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193-204
1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Friday, January 5, 2024 10:09 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Bo York; PB Wells Integrity Subject:UNDER EVALUATION: Producer 11-24A (PTD #1932040) IA casing pressure above MOASP Attachments:11-24A.pdf; TIOChart.jpg Mr. Regg, Producer 11‐24A (PTD # 1932040) was reported to have anomalous IA casing pressure above MOASP on 01/03/24 aŌer the well was shut in. The reported pressure was 2,357 psi. The well will now be classified as UNDER EVALUAITON and is on the 28‐day clock for diagnosƟcs. Plan Forward: 1. DHD: TIFL 2. Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU 11‐24A (PTD 1932040) TIO Pressures Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/29/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221129-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 11-04A 50029204800100 194023 11/4/2022 READ Mult-Array-Pprof PBU 11-24A 50029216230100 193204 11/9/2022 READ Mult-Array-Pprof Please include current contact information if different from above. By Meredith Guhl at 2:00 pm, Nov 29, 2022 T37339 T37340PBU 11-24A 50029216230100 193204 11/9/2022 READ Mult-Array-Pprof Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 14:06:10 -09'00' DIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ORT OF SUNDRY WELL OPERATIONS FEB(F }} 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations 4WGCG Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set HEX Plug Iv1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-204 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21623-01-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 11-24A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9614 feet Plugs measured_ 9348 feet true vertical 9029 feet Junk measured feet Effective Depth: measured 9348 feet Packer measured 8521/8669 feet true vertical 8798 feet Packer true vertical 8110/8238 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 28-108 28-108 1490 470 Surface 2478 13-3/8" 27-2505 27-2505 3450/5380 1950/2670 Intermediate Production 8258 9-5/8" 25-8283 25-7886 6870 4760 Liner 6812 7" 2801-9614 2801-9029 7240/8160 5410/7020 Perforation Depth: Measured depth: 9210-9410 feet True vertical depth: 8681-8851 feetH ' f ,S t%!�` Tubing(size,grade,measured and true vertical depth) 4-1/2",13Cr80 23-8718 23-8279 Packers and SSSV(type,measured and 4-1/2"Bkr S-3 Pkr 8521 8107 true vertical depth) 4-1/2"Bkr SABL-3 Pkr 8669 8238 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 173 4456 9852 1560 297 Subsequent to operation: 432 6454 7812 1531 264 14.Attachments:(required per 20 MC 25.070.25.071,&25.253) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Richards,Meredyth Contact Name: Richards,Meredyth Authorized Title: Petroleum Engineer Contact Email: Meredyth.Richards@bp.com Authorized Signature: 794. �- Date: z// /f 8 Contact Phone: +1 9075644867 Form 10-404 Revised 04/2017 / tin3//1) (p Ae 3 e, RE?DP} tv °";' "18 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary February 15, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Hex Plug and Addition of Perforations for Well 11-24A, PTD # 193-204. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • ami > ) _a > II To o, co- - -o N @ m> Y a) > O N co < E Z O O 06 o C O L O CC () (N D Z N CO CO O CO (0 co I I COCO J o U V C13 3 `-. 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N- ,_CO o o �' 0 0 0 N N N 0 0 V) 10 O N N N N O N (- N > N •- N N m CO O N N 0 Q TREE= , 4-1/16"CIW • WELLHEAD= McEVOY SAFETY NOTE: PARENT(PRE 11-24A)WELLBORE ACTUATOR= BAKER C 11 -24A NOT SHOWN "'4-1/2"CHROME TBG&7"CHROME KB.ELEV= 61.9' LNR"' BF.BEV= NA KOP= 3900' Max Angle= 37"@ 8786' Datum MD= 9414' ' ' 2116' 4-1/2"HES X Nom,D=3.813' Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" H 2505' 9-5/8"X 7"C-2 ZXP LTP,D=6.280" --1 2799' 0 GAS LET MANDRELS 9-5/8"X 7"FLEX-LOC LW.HGR,D=6.280" H 2816° :II ST MD TVD DEV TYPE VLV LATCH PORT DATE ►� 5 2976 2976 0 KGB2 DOME BK r 16 09/26/12 A• 4 4509 4478 24 KGB2 SO BK 20 09/26/12 ►! 3 5623 5486 28 KGB2 DMY BK r 0 02/01/07 7"SCAB LNR,26#,L-80, -I1 8076' ►! � 2 6780 6512 27 KGB2 DMY BK ` 0 02/01/07 BTC-M,.0383 bpf,D=6.250" ► �• 1 7846 7479 22 KGB2 DMY BK ' 0 02/01/07 BKR C-2 TEBACK SLV,D=7.50" H 8079' 9-5/8"X 7"BKR FF PCR,D=6.190" --I 8086' 0 r' 9-518"MILLOUT VIM1VOOW(11-24A) 8283'-8328' 9-518"X 7"BKR HMG HGR ID=6.190" — 8092' 9-5/8"CSG,47//,L 80,D-8.681" H 8283' ' 8500' H4-1/2"FES X IIP,D=3.813' Minimum ID = 3.725" ( 8706° 8521' 7"X 4-1/2" I BKR S 3 F R<R E)=3.870" 4-1/2" OTIS XN NIPPLE 0 I 8545° —4-1/2"HES X NP,ID=3.813' 4-1/2"TBG, 12.6#,13CR-80, H 8608' i / 8617' 7"X 4-1/2"UNIQUE OVERSHOT VAM TOP,.0152 bpf,D=3.958" I/ 8651' -14-112"OTIS X NP,D=3.813" I- 4-1/2"TBG STL13 --1 8617" 14 X. 8669' H7"X 4-1/2'BKR S-3 FKR,D=3.91' ' 8689' H 4-1/2"OTIS X NP,D=3.813" 4-1/2'TBG, 12.6#,13-CR-80,.0152 bpf,D=3.958" 8718' ' 8706' -14-1/2"OTIS XN tom,D=3.725" PERFORATION SUMMARY REF LOG:AWS-Z-DENSCOG ON 02/17/93 \ 8816' H j 7"MARKER JOINT'(19') ANGLE AT TOP PERF:33"@ 9210' Note:Refer to Production DB for historical perf data 8718' H4-1/2"VYLEG,D=3.958" SIZE SR= INTERVAL OpNSgz DATE 3-3/8" 2 9210-9213 S 05/03/98 I 8712' ELMD TT LOGG�03/05194 3-3/8" 6 9213-9219 0 11/14/98 ; 3-3/8" 6 9230-9235 0 05/24/11 3-3/8" 6 9230-9235 0 01/04/06 3-3/8" 4 9264-9268 S 05/03/98 I 3-3/8" 6 9264-9270 0 05/24/11 3-3/8" 6 9264-9270 0 01/04/06 I 9348' I ITERWELL 363-700 FE(PLUG(01/29/18) 2-1/2" 6 9297-9312 0 01/29/18 — — — 3-3/8" 6 9314-9320 0 05/24/11 3-3/8" 6 9314-9320 0 01/04/06 I 3-3/8" 6 9370-9390 C 05/23/11 , 3-3/8" 6 9370-9390 C 03/05/94 - _ , ?? -JFASDRA.L DEBRIS(02/03/07 RM)) 3-3/8" 6 9390-9400 C 05/22/11 3-3/8" 4 9390-9410 C 03/29/94 ••••••1 PBTD -{ 9574' ••i•i•i•i•i•i 7"L , 29#,13CR-80,.0371 bpf,D=6.184" --1 9614' 4,�.416��!•• LNR, DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 01/01/87 ORIGINAL COMPLETION 10/01/12 WEC/JMD GLV C/O(09/26/12) WELL: 11-24A 02/21/94 RIG SIDETRACK 01/31/18 twtS/JM) SET HEX R-UG&ADPERFS FERMIT No: 193-2040 02/03/07 N4ESS RWO AR No: 50-029-21623-01 03/02/07 KSBATLH GLV CJO SEC 28,T11 N,R15E 217'FSL&180'FEL 03/05/07 MWS/PJC DRLG DRAFT CORRECTION 05/31/11 RRD PJC PERFS(05/22-24/11) BP Exploration(Alaska) • Pb'{ c' ( ( -7/�4 Regg, James B (DOA) 1ci 3z-04c From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] cti7. 74, Sent: Thursday, September 27, 2012 9:54 AM Z To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Producer 11 -24A (PTD #1932040) Passing MITIA Confirms Tubing Integrity All, Producer 11 -24A (PTD #1932040) passed an MIT -IA to 3000 psi on 09/26/2012. The passing test confirms 2 competent barriers in the well. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy SANE® OR p 8 2.013 BP Alaska - Well Integrity Coordinator Globe; 'v °fie 115 Or IanIzat;o: WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator (a)BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, September 23, 2012 8:29 AM To: 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)' Cc: AK, D &C Well Integrity Coordinator / Subject: UNDER EVALUATION: Producer 11 -24A (PTD #1932040) Sustaine• - asing IA Pressure Over MOASP Guy, Jim, Producer 11 -24A (PTD #1932040) was found to have IA pr- sure over MOASP during a monitor on 09/22/2012. The wellhead pressures were recorded as T /I /0 = 2370/2 0/0 psi. TIFL's have been performed on 06/23/2012 and 09/15/2012 that passed which is why it had not • - -n reported before this time. The well was already placed as Under Evaluation for slow IA repressurization as no - i in the e -mail below with plans to caliper and perform an MIT -IA after dummying the gas lift valves. Please call if you have any questio' . Thank you, Gerald Murphy 1 • • Li /1- Regg, James B (DOA) 1g340 From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 71/ 1/14117 Sent: Sunday, September 23, 2012 8:29 AM l To: Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer 11 -24A (PTD #1932040) Sustained Casing IA Pressure Over MOASP Attachments: Producer 11 -24A (PTD #1932040) TIO Plot.docx; Producer 11 -24A (PTD #1932040) wellbore schematic.pdf Guy, Jim, v Producer 11 -24A (PTD #1932040) was found to have IA pressure over MOASP during a monitor on 09/22/2012. The wellhead pressures were recorded as T /I /O = 2370/2370/0 psi. TIFL`s have been performed on 06/23/2012 and 09/15/2012 that passed which is why it had not been reported before this time. The well was already placed as Under Evaluation for slow IA repressurization as noted in the e -mail below with plans to caliper and perform an MIT -IA after dummying the gas lift valves. Please call if you have any questions. T DI NED LPR 6 8 n � ef Thank you, S Cf = 2-13 Gerald Murphy MAP 64S > >; BP Alaska - Well Integrity Coordinator - • 4' x1.S ✓ Globale115 Orhan zaFon WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, September 22, 2012 4:15 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East P P Lead; Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: UNDER EVALUATION: Producer 11 -24A (PTD #1932040) Slow IA Repressurization After TIFL All, Producer 11 -24A (PTD #1932040) has exhibited slow IA repressurization following a TIFL performed on 09/14/2012 and being shut -in. The well is reclassified as Under Evaluation. The well may be placed online while work is conducted to attempt to restore integrity. Plan forward: 1. Slickline: Caliper. Set dummy gas lift valves �- 2. Fullbore: MIT -IA to 3000 psi A TIO plot and wellbore schematic are included for reference. Please caJI ifyou have any questions. Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator (�VU �_�o� � ��,Qan//ai'0 |ob�!V� WIC Office: 907.659.5102 WIC Email: }\&DCWo||lntegrkyCoordinator@8P.00m PBU 11 -24A PTD #1932040 9/23/2012 TIO Pressures Plot 1 Well. 11 -24 I I I • 4.OW I 1 i 3.OW- 41 - -- Ub —a— OA 2.000 • OOA —4— 000A I I 1 1.000 i ! • • 0 06'3012 07 //07/12 0714/12 0721112 07/2612 03/04=12 41112 0918112 08/25/12 09/0112 09/08112 09 0922+12 TREE= 4- 1/16" CM/ • SAF Y NOTES: PARENT (PRE 11 -24A) WELLBORE WELLHEAD = McEVOY ACTUATOR = BAKER C 'I 1 -24A NOT SHOWN * * *4 -112" CHROME TBG & 7" CHROME KB. ELEV = 61.9' BF. ELEV = NA 'k 3 900' Max Angle = 37 @ 8786' I 2115' H4 -1/2" HES X NIP, ID = 3.813' I Datum MD = 9414' Datum TV D = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I-I 2505' I.--- 19 -5/8" X 7" C-2 ZXP LTP, ID = 6.280" H 2799' 0 0 GAS LIFT MANDRELS I9 -5/8" X 7" FLEX -LOC LNR HGR, ID = 6.280" H 2816' j l ST MD TVD DEV TYPE VLV LATCH PORT DATE ► *� 5 2976 2976 0 KGB2 DOME BK 16 03/02/07 j• � 4 4509 4478 24 KGB2 SO BK 20 03/02/07 7" SCAB LNR, 26 #, L -80, 8076' : 3 5623 5486 28 KGB2 DMY BK 0 02/01/07 BTC-M, .0383 bpf, ID = 6.250" , .� 2 6780 6512 27 KGB2 DMY BK 0 02/01/07 �• .4 1 7846 7479 22 KGB2 DMY BK 0 02/01/07 BKR C-2 TIEBACK SLV, ID = 7.50" H 8079' Ull I9 -5/8" X 7" BKR HP PKR, ID = 6.190" H 8086' rI 9-5/8" MILLOUT WINDOW (11 -24A) 8283' - 8328' 9 -5/8" X 7" BKR HMC HGR, ID = 6.190" I 8092' /'� --, 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I 8283' I 8500' H4 -1/2" HES X NIP, ID = 3.813' ►-� .13 8521' I-17" X 4 -1/2" BKR S -3 PERM PKR, ID = 3.870" I 8545' f - 14 -1/2" HES X NIP, ID = 3.813' 4 -1/2" TBG, 12.6 #, 13CR -80, -{ 8608' I 8617' H7" X4 -1/2" UNIQUE OVERSHOT VAM TOP, .0152 bpf, ID = 3.958" 8651' I- {4 -1/2" OTIS X NIP, ID = 3.813" I I4 -1/2" TBG STUB H 8617' _ _ ►�� 2 8669' H7" X 4 -112" BKR S -3 PKR, ID = 3.91" I I 8689' H4-1/2" OTIS X NIP, ID = 3.813" I I4 -1/2" TBG, 12.6 #, 13- CR -80, .0152 bpf, ID = 3.958" H 8718' I 8706' 1- 14 -1/2" OTIS XN NIP, ID = 3.725" 1 PERFORATION SUMMARY REF LOG: AWS- Z- DENSILOG ON 02/17/93 L 8816' H7" MARKER JOINT (19') I ANGLE AT TOP PERF: 33 @ 9210' 8718' I-- I4 -1/2" WLEG, ID = 3.958" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 1 I 8712' IH ELMD TT LOGGED 03/05/94 I 3 -3/8" 2 9210 - 9213 S 05/03/98 1 3 -3/8" 6 9213 - 9219 0 11/14/98 1 3 -3/8" 6 9230 - 9235 0 05/24/11 3 -3/8" 6 9230 - 9235 0 01/04/06 , 3 -3/8" 4 9264 - 9268 S 05/03/98 , 3 -3/8" 6 9264 - 9270 0 05/24/11 , 3 -3/8" 6 9264 - 9270 0 01/04/06 , 3 -3/8" 6 9314 - 9320 0 05/24/11 1 3 -3/8" 6 9314 - 9320 0 01/04/06 3 -3/8" 6 9370 - 9390 0 05/23/11 1 3 -3/8" 6 9370 - 9390 0 03/05/94 1 3 -3/8" 6 9390 - 9400 0 05/22/11 • - 1 ®H FASDRILL DEBRIS ( 02/03/07 RWO) I 3 -3/8" 4 9390 - 9410 0 03/29/94 H ������� PBTD I I 9574' I 7" LNR, 29 #, 13CR -80, .0371 bpf , ID = 6.184" H 9614' R ❖W I. 6 n DATE REV BY COMMENTS l DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/01/87 ORIGINAL COMPLETION WELL: 11 -24A 02/21/94 RIG SIDETRACK PERMIT No: 193 -2040 02/03/07 N4ES RWO API No: 50- 029 - 21623 -01 03/02/07 KSB /TLH GLV C/O SEC 28, T11 N, R15E 217' FSL & 180' FEL 03/05/07 MWS/PJC DRLG DRAFT CORRECTION 05/31/11 RRD/ PJC PERFS (05/22- 24/11) BP Exploration (Alaska) STATE OF ALASKA ALASKA OAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate El Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate grAi Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development s Exploratory ❑ 193 -204 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 21623 -01 -00 8. Property Designation (Lease Number) : . 9. Well Name and Number: ADLO- 028325 a PBU 11 -24A 10. Field /Pool(s): u PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9614 feet Plugs (measured) None feet true vertical 9029 feet Junk (measured) Unkn Depth feet Effective Depth measured 9574 feet Packer (measured) 2799. 8086, 8521, 8669 feet true vertical 8994 feet (true vertical) 2799, 7702, 8108. 8238 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 98' 20 ", 91.5 #, H-40 26 - 98 26 - 98 1490 470 Surface 2505' 13 -3/8 ", 72 #, L -80 25 - 2505 25 - 2505 5380 2670 Production 8283' 9 -5/8 ", 47 #, L -80 24 - 8283 24 - 7886 6870 4760 Liner 1535' 7 ", 29 #, 13Cr80 8079 - 9614 7695 - 9029 8160 7020 Scab Liner 5277' 7 ", 26 #, L -80 2799 - 8076 2799 - 7692 t� ti., 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ J V N 2 4 True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 23 - 8718 23 - 8279 Packers and SSSV (type, measured and true vertical depth) 7" C -2 ZXP LTP 2799 2799 7" Baker HP Packer 7702 4 -1/2" Baker S -3 Penn Pac ` 1 ""8 8108 4 -1/2" Baker S -3 Packer i „,„✓, ' $ 8669 8238 12. Stimulation or cement squeeze summary: i ltd ' Intervals treated (measured): ii n r.mat' "iNii11SS1On Treatment descriptions including volumes used and final pressure: ;06138 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 1591 54173 3499 866 Subsequent to operation: 1510 53884 3499 935 14. Attachments: 15. Well Class after work: J Copies of Logs and Surveys Run Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oily 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Elizabeth Barker Printed Name Elizabeth Barker Title Data Manager Signature /6 Phone (907) 564 -5674 Date 6/22/2011 ppRR JUN 24 2011 c L m ..- ./( Form 10 -404 Revised 10 /2(t1s`"' Submit Original Only Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11 -24A 3/5/94 PER 9,370. 9,390. 8,816.85 8,833.94 11 -24A 3/29/94 APF 9,390. 9,400. 8,833.94 8,842.51 11 -24A 3/29/94 APF 9,400. 9,410. 8,842.51 8,851.07 11 -24A 9/10/94 APF 9,210. 9,213. 8,681.46 8,683.98 11 -24A 9/10/94 APF 9,264. 9,268. 8,726.89 8,730.27 11 -24A 5/3/98 SQZ 9,210. 9,291. 8,681.46 8,749.7 11 -24A 11/14/98 RPF 9,213. 9,219. 8,683.98 8,689.02 11 -24A 1/3/06 APF 9,314. 9,320. 8,769.19 8,774.28 11 -24A 1/3/06 APF 9,230. 9,235. 8,698.26 8,702.46 11 -24A 1/3/06 APF 9,264. 9,270. 8,726.89 8,731.95 11 -24A 5/22/11 RPF 9,390. 9,400. 8,833.94 8,842.51 11 -24A 5/23/11 RPF 9,370. 9,390. 8,816.85 8,833.94 • 11 -24A 5/24/11 RPF 9,264. 9,270. 8,726.89 8,731.95 11 -24A 5/24/11 RPF 9,230. 9,235. 8,698.26 8,702.46 11 -24A 5/24/11 RPF 9,314. 9,320. 8,769.19 8,774.28 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 11 -24A 193 -204 PERF ATTACHMENT • • 11 -24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY OACTI g L iu. 4/30/2011 ***WELL FLOWING ON ARRIVAL* ** (pre adperf) :RAN 10' X 3 3/8" DUMMY GUN... ...TAGGED TT @ 8702' SLM ( +10' = 8712' ELM), TAGGED HARD BOTTOM @ 9401' SLM ( +10 = 9411' ELM) OBTAINED SMALL SAMPLE OF FORMATION SAND ** *JOB COMPLETE, WELL LEFT S /I, DSO NOTIFIED * ** 5/22/2011 ***WELL FLOWING ON ARRIVAL * ** (ELINE JEWELRY LOG / PERF) INITIAL T /I /O= 1600/1400/0 WELL FLOWING ON ARRIVAL RIH WITH MH22(6X3) /ERS /UPCT /FIRING HEAD/ 3 3/8" HSD 3406 PJ 6 SPF OAL =19', OAW= 250 #, FISHING HEAD= 1.38" JEWELRY PASS LOGGED FROM 7766' -9404' AND PERFORATED INTERVAL 9390' -9400' 'FINIAL T /I /O= 2150/1500/0 WELL LEFT SI FOR PAD OP TO POP. SWAB, SSV, WING, MASTER OPEN AND OTG ** *JOB CONTINUED ON 23- MAY -11 * ** 5/23/2011; ** *JOB CONTINUED FROM 22- MAY - 2011 * ** (ELINE PERF) LRS LOAD AND KILL WELL INITIAL T /I /O= 360/1140/0 RIH, MH22(6X3), ERS, UPCT, WPSA, FH, 20' 3 -3/8" HSD PJ 6 SPF. OAL =34', OAW= 440 #, FISHING NECK SIZE= 1.38" CCL TO TS= 7.4', PERFORATION INTERVAL= 9370' - 9390', C(<LSTOP DEPTH= 9362.6. PERFORATED INTERVAL 9370' -9390' AT SURFACE VISUAL INSPECTION OF HSD CARRIER REVEAL CRACKS POSSIBLY DUE TO FIRING GUN IN GAS INFORMED PE AND FSM. INSTRUCTED TO RIG DOWN AND RETURN TOMORROW WITH 2 -7/8" PJO GUNS FINAL T /I /0= 1450/ 1140/ 0 PSI WELL LEFT FLOWING SWAB, SSV, WING OPEN AND OTG ** *JOB CONTINUED ON 23- MAY -11 * ** 5/23/2011 ±T /I /0= 2400/1400/0 , Temp =Hot Load and Kill (pre adperf) Pumped 10 bbls neat methanol, 270 bbls 1% kcl, 10 bbls neat methanol and 50 bbls diesel Freeze Protect down tbg. Final WHP= 0/1150/40. SV,WV - closed , SSV,MV,IA OA- open • • • 5/24/2011 ***JOB CONTINUE FROM 24- MAY -11 * ** (ELINE PERF) WELL FLOWING ON ARRIVAL SWAB, SSV, MASTER, WING OPEN RIH WITH MH22 (5X3) /UPCT /FH/ 2 -7/8" 10' HSD PJO 6 SPF 60 DEG, OAL =20', OAW =190# FISHING NECK SIZE= 1.38" CCL TO TOP SHOT= 7.2', PERFORATION INTERVAL 9314' -9320' STOP DEPTH= 9306.8'. SURFACE CONFORMATION OF SHOTS FIRED. RIH WITH MH22 (5X3) /UPCT /FH/ 2 -7/8" 10' HSD PJO 6 SPF 60 DEG, OAL =20', OAW =190# FISHING NECK SIZE= 1.38" CCL TO TOP SHOT= 7.2', 'PERFORATION INTERVAL 9264' -9270' STOP DEPTH= 9256.8'. SURFACE ;CONFORMATION OF SHOTS FIRED. RIH WITH MH22 (5X3) /EQF43 /UPCT /FH/ 2 -7/8" 5' HSD PJO 6 SPF 60 DEG, OAL =19', OAW =190# FISHING NECK SIZE= 1.38" CCL TO TOP SHOT= 3.3', PERFORATION INTERVAL 9230'- 9235', STOP DEPTH= 9256.8'. SURFACE CONFORMATION OF SHOTS FIRED FINIAL T /I /O= 2400/1020/0 WELL LEFT FLOWING MASTER. SWAB, SSV, WING OPEN AND OTG ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 3 METH 270 1% KCL 54 DIESEL 20 NEAT METHANOL 347 TOTAL TREE = 4-1/16" CM/ SAFETY Nt : PARENT (PRE 11 -24A) WELLBORE WELLHEAD = _ ER McEVO_Y NOT SHOW ***4 -1/2" CHROME TBG & 7" CHROME ACTUATOR = BAK C 1 1 -24A KB. ELEV = 61.9' BF. ELEV = NA KOP = 3900' Max Angle = 37 @ 8786' I 2115' I — I4 - 1/2" HES X NIP, ID = 3.813' J Datum MD = 9414' ' Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I — I 2505' 19 -5/8" X 7" C-2 ZXP LTP, ID = 6.280" H 2799' ►.� ►T� GAS LIFT MANDRELS I9 -5/8" X 7" FLEX -LOC LNR HGR, ID = 6.280" H 2816' ST MD TVD DEV TYPE VLV LATCH FORT DATE ►4. !.1 55 2976 2976 0 KGB2 DOME BK 16 03/02/07 j ! 4 4509 4478 24 KGB2 SO BK 20 03/02/07 7" SCAB LNR, 26 #, L -80, - 8076' ! ■ i 3 5623 5486 28 KGB2 DMY BK 0 02/01/07 BTC-M, .0383 bpf, ID = 6.250" � � � � 2 6780 6512 27 KGB2 DMY BK 0 02/01/07 �• '4 1 7846 7479 22 KGB2 DMY BK 0 02/01/07 • BKR C-2 TIEBACK SLV, ID = 7.50" H 8079' .� n . I9 -5/8" X 7" BKR HP PKR, ID = 6.190" H 8086' Ci rL 9 -5/8" MILLOUT WINDOW (11 -24A) 8283' - 8328' I9 -5/8" X 7" BKR HMC HGR, ID = 6.190" I 8092' ./.. 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8283' ( 8500' 1 - 112" HES X NIP, ID = 3.813' I C.1 1-4 8521' J X 4-1/2" BKR S -3 PERM PKR, ID = 3.870" I 8545' 1 HES X NIP, ID = 3.813' I 4 -1/2" TBG, 12.6 #, 13CR -80, —I 8608' 8617' — 17" X 4 -1/2" UNIQUE OVERSHOT VAM TOP, .0152 bpf, ID = 3.958" 8651' 1 OTIS X NIP, ID = 3.813" I I4 -1/2" TBG STUB I-I 8617' II ►�� MI 8669' I X 4 -1/2" BKR S -3 PKR, ID = 3.91" I I 8689' H4-1/2" OTIS X NIP, ID = 3.813" I I4 -1/2" TBG, 12.6 #, 13- CR -80, .0152 bpf, ID = 3.958" H 8718' 8706' H 4 -1/2" OTIS XN NIP, ID = 3.725" I PERFORATION SUMMARY REF LOG: AWS- Z- DENSILOG ON 02/17/93 L 8816' i--17" MARKER JOINT (19') I ANGLE AT TOP PERF: 33 @ 9210' 8718' H4 -1/2" WLEG, ID = 3.958" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 1 I 8712' I-I ELMD TT LOGGED 03/05/94 I 3 -3/8" 2 9210 - 9213 S 05/03/98 1 3 -3/8" 6 9213 - 9219 0 11/14/98 1 3 -3/8" 6 9230 - 9235 0 05/24/11 3 -3/8" 6 9230 - 9235 0 01/04/06 I 3 -3/8" 4 9264 - 9268 S 05/03/98 1 3 -3/8" 6 9264 - 9270 0 05/24/11 1 3 -3/8" 6 9264 - 9270 0 01/04/06 I 3 -3/8" 6 9314 - 9320 0 05/24/11 1 3 -3/8" 6 9314 - 9320 0 01/04/06 3 -3/8" 6 9370 - 9390 0 05/23/11 I 3 -3/8" 6 9370 - 9390 0 03/05/94 1 3 -3/8" 6 9390 - 9400 0 05/22/11 - 1 ?? -I FASDRILL DEBRIS ( 02/03/07 RWO) I 3 -3/8" 4 9390 - 9410 0 03/29/94 •�•�•i•�•�•�•1 PBTD —1 9574' I ►0.0000∎ 17" LNR, 29 #, 13CR -80, .0371 bpf , ID = 6.184" I-1 9614' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/01/87 ORIGINAL COMPLETION WELL: 11 -24A 02/21/94 RIG SIDETRACK PERMIT No: 193 -2040 02/03/07 N4ES RWO API No: 50- 029 - 21623 -01 03/02/07 KSB/TLH GLV C/O SEC 28, T11 N, R15E217' FSL & 180' FEL 03/05/07 MWS /PJC DRLG DRAFT CORRECTION 05/31/11 RRD( PJC PERFS (05/22- 24/11) BP Exploration (Alaska) bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ' '.1 3 d111, 333 West 7 Avenue Anchorage, Alaska 99501 P' " asion 1a;:"r aide Subject: Corrosion Inhibitor Treatments of GPB DS 11 1 I ` ac Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator . • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement _ date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 - 02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 -04A 1 94 0230 50029204800100 NA Sealed NA NA 6/25/2010 11 - 05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11-07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11-08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 1 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed _ NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 - 16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 - 22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 - 24A 193 2040 500292162301 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 - 27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed _ NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 - 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 . STATE OF ALASKA J~'!t. RECEIVED ALA Oil AND GAS CONSERVATION COM.ON 7'1 \ FEB 2 8 2007 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 193-204 ,/ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21623·01-00 ,/ 7. KB Elevation (ft): 54' , 9. Well Name and Number: PBU 11-24A / 8. Property Designation: 10. Field 1 Pool(s): - ADL 028325 . Prudhoe Bay Field 1 Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9614 . feet true vertical 9029 . feet Plugs (measured) None Effective depth: measured 9574 feet Junk (measured) Yes, Unknown Depth true vertical 8994 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 98' 20" 98' 98' 1490 470 Surface 2505' 13-3/8" 2505' 2505' 3450 1950 Intermediate 8283' 9-5/8" 8283' 7886' 6870 4760 Production Liner 1535' 7" 8079' - 9614' 7695' - 9029' 8160 7020 Scab Liner 5277 7" 2799' - 8076' 2799' - 7692' 7240 5410 sCANNED MAR 0 1 2007 Perforation Depth MD (ft): 9213' - 9410' Perforation Depth TVD (ft): 8684' - 8851' 4-112", 12.6# 13Cr80 8717' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer 8521' 7" x 4-112" Baker 'SABL-3' packer 8669' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing from 8615'. Run 7" Scab Liner 2799' - 8076'. Cement wi 150 Bbls Class 'G' (842 cu ft 1726 sx). Ran new chrome comeletion. 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 306-382 Printed Name Terrie Hubble Title Technical Assistant Signature /f'Ô ^rU 0 ~ ~~ Phone 564-4628 02f28~ Prepared By Name/Number: Date '07 Terrie Hubble, 564-4628 - . . Form 10-404 Revised 04/2006 _ (J ! L RBDMS BFL MAR 0 1 2U07 Submit Onglnal Only Digi.tal Wel1file . Well Events for SurfaceWell - 11-24 ~ Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 11 -> 11-24 Date Range: 24/Nov/2006 to 14/Jan/2007 Data Source(s): DIMS, AWGRS Events Source Well Date AWGRS 11-24A 01/14/2007 AWGRS 11-24A 01/09/2007 AWGB,S 11-24A 01/08/2007 AWGRS 11-24A 01/07/2007 AWGRS 11-24A 01/06/2007 8WGR.~ 11-24A 01/05/2007 AWGR5. 11-24A 01/05/2007 8WGRS 11-24A 01/05/2007 A'i'lGR5i 11-24A 12/21/2006 AWGRS 11-24A 11/24/2006 . Page 1 of 1 Description T/IA/OA= 0/0/0 Pre- rig well head MIT PPPOT-T PASSED/PPPOT-IC PASSED Function all LOS on tubing spool, back out of bowl all ok Test 5,000 psi for 30 minutes. Cycle LDs on casing spool,[5] were seized to gland nuts. Was able to free up. All operate good. Test to 3,000 psi for 30 minutes. Bleeder screw was hard to operate. *** 2 1-5/8 studs under AL annulus valve will need to be adjusted during RWO. Well head repair: Pre rig well head MIT. Arrived location, heater was removed. Ordered another. T/I/O= 0/0/0. Freeze Protect TBG, lA, and F/L. Pump 10 bbls of 120* F diesel into the TBG with IA returns to the flowline. U-Tube Tx IA. Freeze protect the flowline. Final WHP= 100/0/0 T/I/O=x/350/40 Circ out well. (PRE RWO) Pumped down the tubing taking returns up the IA through jumper line to cosasco and down the flowline. Pumped 5 bbls meth spear, 200 bbls sea water, 721 bbls 9.8# NaCI Brine, Cap off with 7 bbls diesel, U- Tube TxlA to FP . Bled well to 0 PSI. Freeze protect flowline FWHP's=O/O/O *** WSR continued from 1/5/2007*** Pressure test Fast drill plug to 3200 psi Tbg lost 90 psi in 1st 15 min.and lost 100 psi in 2nd 15 min. for a total loss of 190 psi in 30 min.(Pass) Bled back TBG to 100 psi FWHP's= 100 /750 /80 PREP FOR CHEMICAL CUT OF 4.5" TUBING AT 8620 RUN 1: STRING SHOT FROM 8678' - 8690'.2 STRANDS 80 GRAIN PRIMA CORD. RUN 2: HALIBURTON FASDRILL COMPOSITE BRIDGE PLUG SET MID-ELEMENT AT 8683 FT. TOP OF PLUG AT 8682 FT, BOTTOM AT 8684.5 FT **CONTlNUED 6-JAN-2007 WSR** TlO = 2050/ 750 /0 temp = S/I Assist SLB E-line ( RWO ) Load tubing w/ Spear of 5 bbls 60/40 followed by 129 bbls 1 % KCL @ 130 * then 40 bbls 60/ 40 @ 50 * to freeze protect Tubing ***** WSR Continued on 1/6/2007 Job in progress***** **CONTlNUED FROM 5-JAN-2007** PREP FOR CHEMICAL CUT OF 4.5" TUBING AT 8620 RUN 1: STRING SHOT FROM 8678' - 8690'.2 STRANDS 80 GRAIN PRIMA CORD. RUN 2: HALIBURTON FASDRILL COMPOSITE BRIDGE PLUG SET MID-ELEMENT AT 8683 FT. TOP OF PLUG AT 8682 FT, BOTTOM AT 8684.5 FT RUN 3: TUBINGING PUNCH OVER INTERVAL 8600- 8602 FT WITH SMALL CHARGES. RUN 4: STRING SHOT FROM 8609' - 8621'.2 STRANDS 80 GRAIN PRIMA CORD. RUN 5: CHEMICAL CUT 4.5" TUBING WITH 3-5/8" CUTTER AT 8620'. RETURNED WELL OVER TO DSO UPON DEPARTURE *****]OB COMPLETE***** **** WELL SHUT IN ON ARRIVAL ***(pre-rwo) DRIFT TO TOP OF PXN W/ 3.80" GAUGE RING @ 8687' SLM. PULLED 4 1/2 PXN PLUG @ 8704' SLM. **** JOB COMPLETE, WELL LEFT SHUT IN AND TURNED OVER TO DSO *** T/I/O= 0+/680/40. Temp.= SI. ALP= 680 & is SI @ casing & lateral valves. WHP's. TBG & IA FL (EL). TBG FL near surface. IA FL @ 420' (23 bbls). http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 2/20/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 . ~ 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 1/19/2007 09:00 - 09:30 0.50 RIGD P POST Rig down Nabors 4es and support Modules. 09:30 - 13:00 3.50 RIGD N WAIT POST Waiting on Sows and Bed Trucks to move Rig and support Modules. (Trucks and Drivers tied up on other jobs). 13:00 - 18:00 5.00 MOB P PRE Move Rig and support Modules from DS 1-33 to DS 11. 18:00 - 20:00 2.00 RIGU P PRE Spot Sub, Pits, and Pipe Shed over Well Slot 11-24. Accept Rig at 20:00 hours. 20:00 - 22:00 2.00 RIGU P PRE Raise and Scope up Derrick. 22:00 - 23:00 1.00 DHB P DECOMP P/U DSM Lubricator. Pull BPV and RID. 23:00 - 00:00 1.00 KILL P DECOMP RlU Circulating Lines to Tree for killing operations. Start taking on 9.8 ppg NaCI Brine. 1/20/2007 00:00 - 01 :00 1.00 KILL P DECOMP RlIU Circulating Lines to Tree for killing operations. Offloading 9.8 ppg NaCI Brine. 01 :00 - 03:00 2.00 KILL N DECOMP Wait on Kill Tank from DS-01. 03:00 - 03:30 0.50 KILL P DECOMP RlU Circulating Lines from tree to Kill Tank. 03:30 - 08:00 4.50 KILL P DECOMP Hold Pre-Spud Meeting and PJSM for killing operations. SIDPP- 0 psi, SICP- 30 psi. Reverse circulate 28 bbls of 9.8 ppg NaCI Brine to remove Diesel Cap in Tubing. Line up and pump 9.8 ppg NaCI Brine down the Tubing taking returns out the Annulus to the Kill Tank. Pump rate- 3 BPM with 310 psi pump pressure and 120 psi back pressure on Casing. Total Barrels pumped = 580 bbls. Monitor Well dead. 08:00 - 11 :00 3.00 WHSUR P DECOMP Install and test TWC from bottom at 1000 psi/10 minutes. Good. Test from top at 3500 psi/10 minutes. Good. Record on chart. Blow down lines. Rig down test equipment. Installed 2nd Annulus valve. 11 :00 - 13:30 2.50 WHSUR P DECOMP Nipple-down Production Tree and Adaptor Flange. Secure SSSV Control Line. Inspect Hanger threads. Check 4 1/2" TDS XO threads = 8 1/2" turns. Check Lock-down Screws. 13:30 - 16:00 2.50 BOPSU P DECOMP Nipple-up. BOP Stack, Choke Line, and Kill Lines. 16:00 - 22:30 6.50 BOPSU P DECOMP Rig-up and test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each test was held for 5 minutes. AOGCC right to witness test was waived by Chuck Sheve. Test was witnessed by the Nabors Toolpusher and BP WSL. Test #1- Choke Valves 1, 3, and 12 Test #2- Choke Valves 3, 4, and 5 Test #3· Choke Valves 6, 7, and 8 Test #4- Choke Valves 9 and 10 Test #5- Choke Valve 11 Test #6- Blind Rams, Manual Kill, and Manual Choke Test #7- HCR Kill, and HCR Choke Test #8- Pipe Rams with 3-1/2" Pipe, and Dart Valve Test #9- TIW Valve Test #10- Annular Preventer with 3-1/2" Pipe Test #11- Pipe Rams with 4-1/2" Pipe Test #12- Lower Kelly Valve Test #13- Upper Kelly Valve Accumulater Test- 3,000 psi starting pressure; 1,500 psi after actuation, Fist 200 psi in 35 seconds. Full pressure in 2 minutes and 37 seconds. 4 Nitrogen Bottles at 1,525 psi. 22:30 - 23:30 1.00 DHB P DECOMP Pick up DSM Lubricator and pull TWC Valve. Rig Down DSM Equipment. 23:30 - 00:00 0.50 PULL P DECOMP Pick up Landing Joint. RIH and screw into Hanger with 8.5 Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 1/2012007 23:30 - 00:00 0.50 PULL P DECOMP turns. 1/21/2007 00:00 - 01 :00 1.00 PULL P DECOMP PJSM, BOLDS and pull Hanger to Rig Floor. Max Pull Needed- 104,000 Ibs. 01 :00 - 03:30 2.50 PULL P DECOMP CBU at 5 bpm with 210 psi. RIU Camcol Schlumberger Spooler and Double Decker Power Tongs. RIU Pipe Shed to Lay Down 4-1/2" Tubing. 03:30 - 14:00 10.50 PULL P DECOMP POOH with 4-1/2" tubing and spool single control line. Lay down TRSV. Recovered all bands. Rig-down Spooling Unit. Continue to single down remaing 4-1/2" completion. Recovered 210 Joints, 8 GLM Assemblies, TRSV Assembly, and a Chemical cut Stub = 20.63'. Chem cut good. 14:00 - 15:30 1.50 PULL P DECOMP Rig-down 4-1/2" handling equipment. Clear and clean floor. 15:30 - 16:00 0.50 PULL P DECOMP Rig-up to handle BHA and 3-1/2" Drill Pipe. 16:00 - 18:00 2.00 FISH P DECOMP Make-up BHA #1 as follows: 6" x 4-1/2" Shoe, 3 ea Extentions, Drive Sub, XO, 7" Casing Scraper, 2 ea Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, Drill Collars and RIH. Total length of BHA- 232.07'. Total swallow- 12'. 18:00 - 00:00 6.00 FISH P DECOMP Pick up 3-1/2" Drill Pipe from Pipe Shed and RIH with BHA #1. Tag top of Liner at 8070' MD. 1/22/2007 00:00 - 00:30 0.50 FISH P DECOMP Pick up 3-1/2" Drill Pipe from Pipe Shed and RIH with BHA #1. Picked up a total of 265 Joints. Tag top of Tubing Stump at 8617' MD. 00:30 - 01 :00 0.50 FISH P DECOMP Pick up Kelly, and establish Parameters of 130,000 Ibs up weight, 118,000 Ibs down weight, 125,000 Ibs free rotating weight at 50 RPM with 2700 ft-Ibs Torque, pumping at 3 BPM with 440 psi. 01 :00 - 03:00 2.00 FISH P DECOMP Work over Tubing Stump at 8617' to 8629'. Tight spot from 8617' to 8621'. Increase RPMs to 60 RPM and Pumps to 4 BPM with 940 psi. WOB from 5,000 Ibs to 15,000 Ibs to work through tight spot the first time. Torque increased to 3250 ft-Ibs. WOB drilled off slow, but consistently. Once Rotary Shoe worked past 8621', all WOB was lost from 8621' to 8629' MD. Worked over tight spot several times without any significant improvement or change. No signs of metal or fill was noted coming across shakers. 03:00 - 05:30 2.50 FISH P DECOMP Pump a High Viscocity Sweep at 5 BPM with 920 psi without any noticable cuttings. 05:30 - 06:00 0.50 FISH P DECOMP Set back Kelly. POOH with BHA #1 standing back 3-1/2' Drill Pipe in Derrick. 06:00 - 06:30 0.50 FISH P DECOMP Service Rig. Check Alarms. 06:30 - 10:30 4.00 FISH P DECOMP Continue tripping-out with 3-1/2" Drill Pipe and BHA #1. Inspect BHA. 6" Shoe was shiney on the outside and barand new on the inside. 10:30 - 11 :30 1.00 FISH P DECOMP Lay down Shoe, Extentions and Casing Scraper. Empty Boot Baskets. Recover a small handfull of fill material. 11 :30 - 12:30 1.00 FISH P DECOMP Have the Unique Overshot that is going to be used for the Completion delivered to location. Make-up BHA as follows: <6" x 4 5/8" Unique Overshot, 4 1/2" Tubing Pup Jt, XO, XO, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jar, 6 ea Drill Collars. 12:30 - 16:30 4.00 FISH P DECOMP Trip in with BHA #2 and 3-1/2" Drill Pipe. PUW = 125K. SOW = 115K. Bring Pump on line at 3.0 bpm/525 psi. Slack-off and tag top of 4-1/2" Stump at 8,619'. Start to swallow Stump and Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 1/22/2007 12:30 - 16:30 4.00 FISH P DECOMP pump pressure increased to 700 psi. Shut down Pump. Continue to swallow Stump down to 8,627'. Pull off of Stump. Dry tag top of Stump again at same place and continue to swallow down to 8,627'. Stack weight (5K). Bring Pump on line slowly. Pressure rapidly climbed to 850 psi in just a few strokes. Shut down pump. Pull up and the pressure dropped to 0 psi. 16:30 - 20:30 4.00 FISH P DECOMP Trip-out 3-1/2" Drill Pipe and BHA #2. 20:30 - 21 :30 1.00 FISH P DECOMP POOH with BHA #2. Stand back Drill Collars in Derrick. Lay down Unique Overshot. 21 :30 - 22:00 0.50 FISH P DECOMP Clear and clean Rig Floor. 22:00 - 00:00 2.00 FISH P DECOMP Pick up HES RBP and Running Tool. RIH on 3-1/2" Drill Pipe from Derrick. 1/23/2007 00:00 - 02:30 2.50 DHB P DECOMP RIH with HES RBP on 3-1/2" Drill Pipe to Top of Liner at 8070' MD. Establish Parameters of 122,000 Ibs up weight and 113,000 Ibs down weight. Continue RIH working through the top of liner and set RBP at 8153' MD. 02:30 - 06:00 3.50 DHB P DECOMP Dump 50' of 20 x 40 Mesh River Sand on top of RBP. Circulate 1 hole volume at 1 BPM to clear sand from Drill Pipe. Allow Sand to settle. 06:00 . 07:00 1.00 DHB P DECOMP Service rig, check crown 0 matic & PVT system, OK. 07:00 . 07:30 0.50 DHB P DECOMP Tag sand top at 8106' DPM. 07:30 - 10:00 2.50 DHB P DECOMP PJSM. POOH with HES RBP Running Tool standing back 3 1/2" Drill Pipe. 10:00 - 10:30 0.50 DHB P DECOMP PJSM. UD Halliburton Running Tool. 10:30 - 11 :30 1.00 CASRE P INTERV PJSM. Pick up BHA #3, polish mill assembly consisting of Polish Mill, 3-1/2" Drill Pipe Pup Jt, X/O Sub, 9·5/8" Casing Scraper, 7" Boot Basket, Bit Sub, Bumper Sub, Jars and Drill Collars picked up from Derrrick. Total length of BHA-228.33'. 11 :30 - 15:00 3.50 CASRE P INTERV PJSM. RIH with polish mill assembly on 3 1/2" Drill Pipe, (82) stands, (1) single & 10' pup. 15:00 - 15:30 0.50 CASRE P INTERV PJSM. Kelly up and establish parameters. 127K up wt, 115K down wt, 120K rotating wt. Bring on pump @ 3 1/2 bpm, 500 psi. Polish off top of liner at 8070' with 5 -12K WOB, seeing 8500 ftllbs of torque, total milling time 30 minutes. Run back in without rotating or pumping, entered liner wi no bobbles. . 15:30 . 17:30 2.00 CASRE P INTERV PJSM. Mix and circulate 40 bbls High Viscosity Sweep around at 5 1/2 bpm 11000 psi. 17:30 - 18:30 1.00 CASRE P INTERV PJSM. Service Rig. Slip and Cut 84' of Drill Line. 18:30 - 23:30 5.00 CASRE P INTERV POOH with Polishing Mill. Stand back 3 1/2" Drill Pipe in Derrick. 23:30 - 00:00 0.50 CASRE P INTERV PJSM. POOH with BHA #3. Stand back 2 stands of Drill Collars. Lay down Jars, Bumper Sub, Boot Basket, Scraper, Subs, and Polish Mill. Polish Mill showed wear from Liner Top. Boot Basket had approximatly 2 cups of metal shavings and one piece of CMT. 1/24/2007 00:00 - 01 :00 1.00 CASRE P INTERV PJSM. POOH with BHA #3. Stand back 2 stands of Drill Collars. Lay down Jars, Bumper Sub, Boot Basket, Scraper, Subs, and Polish Mill. Polish Mill showed wear from Liner Top. Boot Basket had approximatly 2 cups of metal shavings and one piece of CMT. 01 :00 - 01 :30 0.50 CASRE P INTERV PJSM. Rig down BOP Riser and Flow Line. 01 :30 - 02:30 1.00 CASRE P INTERV Rig up Shooting Flange on top of BOPE and NU. Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 Move in and rig up Schlumberger Wireline Services E-Line Unit. M/U US IT Logging Tool and RIH. Pressure Test SWL Lubricator to 500 psi and hold for 5 min. Good Test, charted results. Run USIT Log in hole. Log up in Low Resolution mode from top of Liner at 8040' ELM to surface. Change out tool package. ' RIH with US IT and log up from 7000' to 3500' ELM in High Resolution mode at 400' I hr. POOH with Schlumberger USIT Logging Tools and rig down Wireline Equipment. PJSM. Rig down Shooting Flange. Rig up Bell Nipple and Flow line. PJSM. Rig up Handling Tools and rig up Floor to run 7", 26#, L-80, BTC-M Casing. Pick up 7" Scab Liner Bottom Hole Jewelry and RIH. Baker-Loc all connections of BHA. Continue picking up 7", 26#, L-80, BTC-M Casing and RIH. Running 1 free-floating straight-vaned Centralizer every other Joint for the first 50 Joints in the hole. Using Best-O-Life Pipe Dope on connections above the BHA. Making each connection up the mark. INTERV Continue in hole as stated above, torque turning each connection to 8500 ft /lbs, making up to middle of knurl mark, filling pipe every 5 jts wi 9.8 ppf brine. Run (1) centralizer per joint on #50 - #100. Run 127 jts & make up 7" x 9 5/8" FlexLock liner hanger, 7" x 9 5/8" C-2 ZXP liner top packer & 7" hydraulic pusher tool as per Baker hand. INTERV PJSM. Clear I clean rig floor & make up head pin to circulate liner volume. INTERV PJSM. Circulate 205 bbls of 9.8 ppg, 95 degree brine @ 3 1/2 bpm 1150 psi, OK. INTERV Continue RIH with 7" Scab Liner on 3 1/2" Drill Pipe from Derrick to the top of Liner at 8070'. INTERV Establish Parameters of 162,000 Ibs up weight and 152,000 Ibs down weight. Space out Seal Assembly with 7" Tie-Back Receptacle. Sting into Tie-Back Receptacle and pressure up to 500 psi. Hold pressure for 10 minutes to verify seals holding. POOH slowly until 500 psi bled off as circulating port came out of PBR. Continue POOH 1'. PJSM. Rig up Cement Head and circulating lines. Spot and rig up Schlumberger Cementers. Cementers Micro Motion Sensor quit working. Changed out Pumping Units. Pump 10 bbls of water from Cementers through cement lines. Pressure Test Lines to low pressure of 800 psi and high pressure to 4000 psi. Test Failed, bleed off pressure. Change out Cement Line. Pressure Test to low pressure of 800 psi and high pressure of 4000 psi. Good Test. TIEB1 Pump 150 bbls of 15.8# Class "G" Cement. Drop Plug and displace with 218.7 bbls of 9.8 ppg Brine. Bump Plug with 2200 psi. 04:30 - 05:00 INTERV 05:00 - 11 :00 INTERV 11 :00 - 12:00 INTERV 12:00 - 23:30 INTERV 23:30 - 00:00 INTERV 1/25/2007 00:00 - 02:30 INTERV 02:30 - 03:30 INTERV 03:30 - 05:00 INTERV 05:00 - 06:00 INTERV 06:00 - 15:30 15:30 - 16:30 1.00 CASRE 16:30 - 17:30 17:30 - 20:00 20:00 - 22:00 2.00 CASRE 22:00 - 23:00 1.00 CASRE P INTERV 23:00 - 00:00 1.00 CASRE N INTERV 1/26/2007 00:00 - 01 :30 1.50 CEMT P TIEB1 01 :30 - 03:30 2.00 CEMT P Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 TIEB1 Bleed off pressure and slack off Casing Liner to No-Go. Stack 10,000 Ibs on No-Go. Pressure up to 3000 psi to set Liner Hanger. Slack off 120,000 Ibs of Liner Hanger. Pressure up to 3600 psi to set Liner Packer. Rotate 15 right turns to release Liner Running Tool. Pressure up to 500 psi and POOH 25'. Reverse circulate out excess Cement. PJSM. Clear I clean rig floor, rig down cementers. PJSM. POOH wi 3 1/2" DP & running tool. PJSM. NID BOPE & flow riser. PJSM. Change out 9 5/8" pack off, (some trouble pulling bolts on top plate). NOTE: UCA on cement @ 1000 psi & climbing @ 11:00 hrs. PJSM. NIU new tubing spool & test pack off. Test void @ 3950 psi I 30 minutes, good test. PJSM. NIU 13 5/8" x 5M BOPE & flow riser. Test BOPE to 250 psi low pressure and 3,500 psi high pressure. Each Test was held for 5 Minutes. AOGCC Witnessed Test by Lou Grimaldi. Test witnessed by AOGCC Lou Grimaldi, Nabors Toolpusher, and BP WSL. Test #1- Choke Valves 1,2,12, and Blind Rams. Test #2- Choke Valves 3,4, and 5. Test #3- Choke Valves 6, 7, and 8. Test #4- Choke Valves 9, and 10. Test #5- Choke Valve 11. Test #6- Choke Valve 15. Test #7- Choke Valve 13. Test #8-KiII and Choke Line HCR Valves. Test #9- Kill and Choke Line Manual Valves. Test #10- TIW Valve and Pipe Rams on 3-1/2" Test Joint. Test #11- Annular Preventor. Test #12- Dart Valve and Pipe Rams on 4-1/2" Test Joint. Test #13- 2" Mud Valve. Test #14- Lower Kelly Valve. Test #15- Upper Kelly Valve. INTERV Test BOPE to 250 psi low pressure and 3,500 psi high pressure. Each Test was held for 5 Minutes. Test witnessed by AOGCC Lou Grimaldi, Nabors Toolpusher, and BP WSL. Accumulater Test- 3,000 psi starting pressure; 1,500 psi after actuation. First 200 psi in 35 seconds; full pressure in 2 minutes 26 seconds. 4 Nitrogen Bottles at 1,412 psi. Drain Stack and pull Test Plug. Install Wear Ring. Clear and Clean Rig Floor. Pick up BHA #4 Drilling Out Assembly consisting of 6-1/8" Used Bit, 2 Boot Baskets, 7" Scraper, Bit Sub, Bumper Sub, Jars, and 6 Drill Collars. Picked up Drill Collars from Derrick. RIH with BHA #4 on 3-1/2" Drill Pipe from Derrick. Ran 77 Stands in the hole. Desision to POOH and change out used bit. POOH with BHA #4. Stand back 3-1/2" Drill Pipe in Derrick. Service rig, check crown 0 matic, PVT system, OK. PJSM. Continue POOH wI 3 1/2" DP. PJSM. Stand back collars, UD used bit in questionable 1/26/2007 03:30 - 04:30 1.00 CEMT P 04:30 - 05:30 1.00 CEMT P TIEB1 05:30 - 07:00 1.50 CEMT P TIEB1 07:00 - 09:30 2.50 BOPSU P INTERV 09:30 - 11 :00 1.50 WHSUR P INTERV 11 :00 - 14:30 3.50 WHSUR P INTERV 14:30 - 16:00 1.50 BOPSU P INTERV 16:00 - 00:00 8.00 BOPSU P INTERV 1/27/2007 00:00 - 00:30 0.50 BOPSU P 00:30 - 02:00 1.50 BOPSU P INTERV 02:00 - 03:30 1.50 CLEAN P CLEAN 03:30 - 05:00 1.50 CLEAN P CLEAN 05:00 - 06:00 1.00 CLEAN N CLEAN 06:00 - 07:00 1.00 CLEAN N CLEAN 07:00 - 10:30 3.50 CLEAN N CLEAN 10:30 - 11 :30 1.00 CLEAN N CLEAN Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 1/27/2007 10:30 - 11 :30 1.00 CLEAN N CLEAN condition. 11 :30 - 12:30 1.00 CLEAN P CLEAN Clear and clean rig floor. 12:30 - 13:00 0.50 CLEAN P CLEAN PJSM. Pick up new medium tooth rock bit. 13:00 - 16:00 3.00 CLEAN P CLEAN PJSM. RIH with shoe track milling assembly on 3 1/2" DP. 81 stands + 22', tag up @ 7928' DPM. 16:00 - 23:00 7.00 CLEAN P CLEAN PJSM. Kelly up & establish parameters. 130K up wt, 110K down wt, 120K rotating wt. Rotating @ 80 RPM, off bottom torque = 110 amps or 2200 tV Ibs. Pumping 4112 bpm @ 800 psi, 5 -10K WOB, torque on bottom is 160 amps or 3200 tVlb~h{ Commence milling cement above landing collar. Top of (., / cement at 7928' DPM. Drill out landing collar at 8008'. Drilled out float at 8049'. Continue drilling cement to 8101' DPM. Continue to washing sand to 8106'. 23:00 - 00:00 1.00 CLEAN P CLEAN Pump 20 bbl high viscosity sweep at 5 bpm and 1080 psi. 1/28/2007 00:00 - 02:00 2.00 CLEAN P CLEAN Pump high viscosity sweep and follow with 275 bbls of 8.5 seawater to displace to seawater at 5 BPM with 1080 psi. 02:00 . 06:00 4.00 CLEAN P CLEAN POOH from 8106' with drill out assembly standing back 3-1/2" drill pipe in derrick. 06:00 - 07:00 1.00 CLEAN P CLEAN Service rig, check PVTs, crown 0 matic, OK. 07:00 - 08:00 1.00 CLEAN P CLEAN Continue to POOH w/3 1/2" DP & shoe track milling BHA. 08:00 - 09:30 1.50 CLEAN P CLEAN PJSM. UD bit, empty junk subs, M/U reverse circulating junk basket BHA. 09:30 - 11 :00 1.50 CLEAN P CLEAN PJSM. Ensure hole is full, close blind rams, open O/A. Pressure 9 5/8" x 7" casing from surface to top of sand @ 8106' to 3500 psi 130 minutes I charted. Test is solid wi no indication of communication wi OIA. Bleed off all pressure, shut in OIA, clear floor. 11 :00 - 14:30 3.50 CLEAN P CLEAN PJSM. RIH wi RCJB assembly on 3 1/2" DP, 83 stands. Break circulation half way in to verify all clear, OK. Drop ball wi 83 stands in. 14:30 - 15:00 0.50 CLEAN P CLEAN PJSM. Kelly up & establish parameters. 139K up wt, 114K down wt, 125K rotating wt. Circulate ball on down & observe ball on seat & pressure climb to 1200 psi @ 5 1/4 bpm. Dry tag 7' in on kelly @ 8107'. Rotate slowly & wash to 8120' wI RCJB. Stand back kelly. 15:00 - 20:00 5.00 CLEAN P CLEAN PJSM. POOH wi 3 1/2" DP & RCJB assembly. Rack back 3-1/2" drill pipe in derrick. 20:00 - 21 :00 1.00 CLEAN P CLEAN PJSM. POOH wi BHA #5 RCJB. Stand back drill collars. Break out RCJB and empty. Contents were 3 small pieces of cement. Boot baskets were full of sand. 21 :00 - 21 :30 0.50 CLEAN P CLEAN Clear and clean rig floor. 21 :30 - 22:30 1.00 CLEAN P CLEAN PJSM. Pick up RCJB extension. Make up BHA #6 with RCJB, 2 boot baskets subs, bit sub, bumper sub, jars, and 6 drill collars. Total length of BHA= 220.01'. 22:30 - 00:00 1.50 CLEAN P CLEAN RIH wI BHA #6 on 3-1/2" drill pipe picked up from derrick. 1/29/2007 00:00 - 01 :30 1.50 CLEAN P CLEAN Continue RIH wi RCJB Run #2 on 3-1/2' drill pipe from derrick. 01 :30 - 02:00 0.50 CLEAN P CLEAN Pick up kelly and establish parameters of 135,000 Ibs up weight, 114,000 Ibs down weight, 125,000 Ibs rotating weight at 30 rpm and 2800 ft-Ibs torque, pump at 3 bpm with 370 psi. Drop,'" """ ,,, RCJB. ~ 02:00 - 07:00 5.00 CLEAN N RREP CLEAN While operating hydraulic tugger, discharge line coming off hydraulic pump failed, causing spillage of 131 gallons of (.,l" 11 Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 1/29/2007 02:00 - 07:00 5.00 CLEAN N RREP CLEAN hydraulic fluid, 126 gallons contained in containment, 5 gallons on gravel pad. Cleaning up gravel & rig. 07:00 - 08:30 1.50 CLEAN P CLEAN PJSM. Tag up @ 8120, wash down to 8135', make connection & wash on down to top of bridge plug @ 8153'. 08:30 - 11 :00 2.50 CLEAN P CLEAN PJSM. Circulate 40 bbls Hi Vis sweep around @ 6 bpm 11460 psi, seeing significant amount of sand across shaker. 11 :00 - 11 :30 0.50 CLEAN P CLEAN Service rig, check crown 0 matic, PVTs, derrick inspection, OK. 11 :30 - 15:00 3.50 CLEAN P CLEAN PJSM. POOH wi 3 1/2" DP & RCJB. 15:00 - 16:30 1.50 CLEAN P CLEAN PJSM. Stand back collars, clean sand out of junk subs, inspect junk basket... (1) small piece of trash, UD RCJB assembly, M/U Halliburton bridge plug retrieving tool. 16:30 - 20:30 4.00 CLEAN P CLEAN PJSM. RIH wi Halliburton bridge plug retrieving tool to top of bridge plug at 8153'. Establish parameters of 130,000 Ibs up weight, 106,000 Ibs down weight. 20:30 - 21 :00 0.50 CLEAN P CLEAN Latch up to HES RBP and reverse circulate one drill pipe volume at 2.7 bpm with 930 psi. 21 :00 - 22:30 1.50 CLEAN P CLEAN Work drill string with 30,000 Ibs overpull to relax elements and unseat HES RBP. POOH to 8080'. HES RBP stuck. Attempt to work free. Reset HES RBP and unlatch from retrieving tool. 22:30 - 00:00 1.50 CLEAN P CLEAN Reestablish parameters of 130,000 Ibs up weight, and 106,000 Ibs down weight. Latch onto bridge plug. Work drill string with 60,000 Ibs over pull, and set 5,000 Ibs on plug. Work several times to relax and unseat bridge plug. 1/30/2007 00:00 - 00:30 0.50 CLEAN P CLEAN Continue to work drill string with 60,000 Ibs over pull, and set 5,000 Ibs on bridge plug. After several attempts to relax elements and unseat the bridge plug, it worked free. 00:30 - 02:00 1.50 CLEAN P CLEAN Confirmed the bridge plug was unseated. CBU at 5.2 bpm with 980 psi. Monitor well stable. 02:00 - 06:00 4.00 CLEAN P CLEAN Verified the bridge plug on the drill string. POOH with HES RBP and stand back 3-1/2" drill pipe in derrick. UD Halliburton bridge plug & retrieving tool. 06:00 - 07:00 1.00 CLEAN P CLEAN PJSM. Service rig, check PVT system & crown 0 matic, OK. 07:00 - 09:00 2.00 CLEAN P CLEAN PJSM. M/U 3 5/8" bladed junk mill milling BHA to mill up composite bridge plug. 09:00 - 12:00 3.00 CLEAN P CLEAN TIH with BHA #7 with DP from the Derrick. Tag Stump @ 8,620' and shear pins with 20K down. 12:00 - 14:30 2.50 CLEAN P CLEAN PU and MU Kelly. Push Rubber down from 8,630' to 8,683'. Pumping at a rate of 4 bpm I 750 psi. 14:30 - 15:30 1.00 CLEAN P CLEAN Rotate and mill up Composite Plug from 8,683' to 8,684' while pumping at a rate of 4 bpm I 600 psi. Lost returns once Plug was drilled up. Continue pushing Plug out of Tailpipe to final depth of 8,726'. 15:30 - 21:00 5.50 CLEAN P CLEAN TOH with BHA #7 laying down single Joints of DP in the Pipe Shed while double displacing with seawater. 21 :00 - 22:00 1.00 CLEAN P CLEAN PJSM. Cut and slip 84' of Drilling Line. 22:00 - 22:30 0.50 CLEAN P CLEAN Safety Meeting: Stop Training for Employees with Rig Crew. 22:30 - 00:00 1.50 CLEAN P CLEAN Continue TOH double displacing with seawater laying down DP in the Pipe Shed. 1/31/2007 00:00 - 02:00 2.00 CLEAN P CLEAN Continue TOH with BHA #7. Double displacing the well with seawater and laying down DP in the Pipe Shed. 02:00 - 04:00 2.00 CLEAN P CLEAN On surface with Drill Collars. Break and lay down Drill Collars. On surface with BHA #7. Inspect Mill Assembly and everything Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -24 11 -24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/1 9/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 is good. Break down and lay down components with Baker rep. Pull Wear Ring. Clear and clean Rig Floor. RU to run 4 1/2" Completion. Load Completion Assemblies into Pipe Shed. 06:00 - 07:00 1.00 RUNCMP Pre-tour meeting, service rig, confirm all jewelry components ready to run. 07:00 - 08:30 1.50 RUNCMP M/U & RIH with tailpipe assembly and S-3 packer. All connections Baker-Locked below packer. RIH with 4.5", 12.6#/ft, 13Cr-80 VamTop completion. Torque Turn VamTop connections to 4,440 ft-Ibs. Used Jet Lube Sealguard pipe dope. 08:30 . 18:00 WAIT RUNCMP Winds gusting 45+ mph blowing blocks into derrick man on stabbing board. Derrick man having to manually push blocks as blocks are lowered past stabbing board. Shut down operations, maintain periodic seawater injection & monitor wind. 18:00 - 00:00 WAIT RUNCMP Pre-tour safety meeting and service Rig. Check PVT Alarms - OK. Continue to wait on weather. Winds still gusting to 40+ mph. The current conditions are Phase 2 on main roads and Level 3 on access roads and pads. 2/1/2007 00:00 - 06:00 WAIT RUNCMP Continue to wait on weather. The conditions remain Phase 2 on main roads and Level 3 on access roads and pads. The wind has begun to subside but the wind direction is such that the Blocks are still being blown directly at the Stabbing Board making it unsafe. Maintain Rig and perform maintenance. Crew finished Stop Training for Employees. At 02:45 hrs, the conditions are now Level 2 on main roads and Level 3 on access roads and pads. Spoke with Roads and Pads at 03:30 hrs and they just cleared our location and access road for change out. Due to Level 3 conditions on access roads and pads, decision made to wait until change out to resume operations. 06:00 - 07:30 1.50 RUNCO RUNCMP Pre-tour mtg & PJSM on completion running. Service rig & derrick inspection after the blow. 07:30 - 18:00 10.50 RUNCO RUNCMP RIH with 4.5", 12.6#/ft, 13Cr-80 VamTop completion per running order using single jt compensator. Torque-turning each connection to 4440 ft-Ibs. No problems entering 7" scab liner top. 18:00 - 18:30 0.50 RUNCO RUNCMP Pre-tour safety meeting. Service Rig, Derrick inspection and PVT Alarms - OK. 18:30 - 21:00 2.50 RUNCO RUNCMP Continue RIH with 41/2", 12.6# 13Cr-80 Varn Top Completion per running order. All connections torque-turned to 4,400 ft-Ibs. Utilizing stabbing guide and Jet Lube Seal Guard on each connection. 21 :00 - 21 :30 0.50 RUNCO P RUNCMP Tag the Stump 18' in on Joint #201 = 8,615'. Stack 8K down and begin swallowing the Stump. Sit down on Shear Pins 22' in on Joint #201 = 8,619'. Stack 6K and observe the Shear Pins break. Began taking weight 23' in on Joint #201 = 8,620'. This gives 5' of swallow when we should have 8'. PU and RIH again and bottom out at same depth of 8,620' (did not see the Stump the second time). Completion String PUW = 112K , SOW = 97K. 21 :30 - 22:30 1.00 RUNCO RUNCMP PU and MU Headpin on the Tubing. Break circulation at a rate Printed: 2/5/2007 7:06:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-24 11-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2007 Rig Release: 2/2/2007 Rig Number: Spud Date: 6/27/1986 End: 2/2/2007 of 3 bpm 130 psi (well is not full due to vac) in an attempt to clear anything that may be in the way from swallowing the extra 3'. RIH while circulating and bottom out at same depth of 8,620'. Attempt several times to get deeper - No Joy. 22:30 - 23:30 RUNCMP Break off Headpin and space out. Will need 39' of Pup Joints for 2' off bottom space out. Lay down Joint #'s 201, 200 and 199. PU and bury (4) space out Pup Joints. PU and MU Joint #199 to String. The bottom of the Overshot will be at 8,617'. 23:30 - 00:00 0.50 RUNCMP PU and MU Tubing Hanger Assembly with Cameron rep. Land Hanger with no problems. RILDS with Cameron. 2/2/2007 00:00 - 02:00 2.00 RUNCMP Line up to pump down the Annulus Valve. Break circulation with 140 degree inhibited 1 % KCL down the Annulus at a rate of 3 bpm I 30 psi. 02:00 - 03:00 RUNCMP Drop Ball and Rod with Baker reps. Pump down the Tubing with Charge Pump to fill up the Tubing with 140 degree 1% KCL. 03:00 - 03:30 RUNCMP Close Blind Rams and pressure up on the Tubing to 3,500 psi to set the Packer. Hold 3,500 psi to pressure test the Tubing. During pressure test, the Test Spool on the BOPE began leaking above and below the API Ring. Shut down and bleed off Tubing Pressure. 03:30 - 04:00 0.50 RUNCMP PJSM on Sweeney Wrench Operation. Re-tighten up bolts on Test Spool. 04:00 - 06:00 2.00 RUNCMP Pressure up on Tubing and test to 3,500 psi for 30 mins - OK. Bleed Tubing pressure down to 1,500 psi. Line up to pump down the IA. Fill up the IA with hot 1 % KCL. Took 13 bbls to fill. Pressure up the IA to 3,500 psi, the Tubing increased to 2,100 psi. Test the IA to 3,500 psi for 30 mins - OK. Bleed the Tubing pressure and observe DCK Shear - OK. Confirm circulation in both directions thru DCK - Good. 06:00 - 07:30 1.50 WHSUR P RUNCMP Pre-tour mtg, PJSM on ND operations. Cameron set TWC. Test from below and above to 1000 psi. Good test. 07:30 - 11 :30 4.00 BOPSU P RUNCMP Drain stack, blow down pump and lines, ND BOP stack and set back on stand for rig move. 11 :30 - 13:30 2.00 WHSUR P RUNCMP NU McEvoy 13-5/8" x 4-1/16" 5M adapter flange. PT tbg hanger seals to 5000 psi f/30-min (OK). NU 4-1/16" 5M tree (same tree as when we got here, refurbished at DSM). PT tree to 5000 psi (GOOD). 13:30 - 15:00 1.50 WHSUR P RUNCMP DSM rigged up lubricator & pulled TWC. 15:00 - 19:00 4.00 RUNCO P RUNCMP PJSM on freeze protection plan. RU LRS hot-oilers. PT line to 3500 psi. Pump heated (80 degF) diesel down the annulus. Pump 140 bbls. U-tube for 1-hr. Pre-tour safety meeting and checks - OK. Open well up after U-tubing for 1 hour and suck back with Little Red, got approximately 1 bbls back. Well is dead. 19:00 - 21:00 2.00 WHSUR P RUNCMP PU and set BPV with Cameron rep. Test the BPV to 1,000 psi from below for 10 mins charted - Good. Secure Well and Cellar. Call out Drill Site Operator to inspect Tree - everything OK and he will flag Valves on the Tree once we move off of Well. Released Rig at 21 :00 hrs on 2/2/2007. / Printed: 2/5/2007 7:06:42 AM mEE "', 4-1/16" CrN W8.LHEAD = McEVOY ACTUA TOR = BAKER C KB. 8.EV = 61.9' SF. aEV = NA KOP = 3900' Max Angle = 37 @ 8786' Datum MD = 9414' Datum IVD:= 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I PJC DRAFT . 11-24A SAFaTES: PARENT (PRE 11-24A) W8..LBORE NOT N ***4-1/2" CHROMETBG & 7" CHROME 2115' -14-1/2"HESXNIP,ID=3.813' I /4-1/2" TBG, 12.6#. 13-CR-80, .0152 bpf, ID = 3.958" I 8717' ÆRFORA TION SUMMARY REF LOG: AWS-Z-DENSILOG ON 02/17/93 ANGLE AT TOP ÆRF: 33 @ 9210' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 2 9210 - 9213 S 05/03/98 3-3/8" 6 9213 - 9219 0 11/14/98 3-3/8" 6 9230 - 9235 0 01/04/06 3-3/8" 4 9264 - 9268 S 05/03/98 3-3/8" 6 9264 - 9270 0 01/04/06 3-3/8" 6 9314 - 9320 0 01/04/06 3-3/8" 6 9370 - 9390 0 03/05/94 3-3f8" 4 9390 - 9410 0 03f29/94 19-5/8" X 7" C-2 ZXP L TP, ID:= 6.280" I 9-5f8" X 7" FLEX-LOC LNR HGR, ID:= 6.280" 7" SCAB LNR, 26#, L-80, BTC-M, .0383 bpf, ID = 6.250" IBKR C-2 TIEBACK SLV. ID = 7.50" I 9-5f8" X 7" BKR HP PKR, ID = 6.190" I 9-5f8" X T' BKR HMC HGR. ID = 6.190" I 9-5/8" CSG, 47#. L-80. ID = 8.681" I Minimum ID = 3.725" @ 8706' 4-1/2" OTIS XN NIPPLE 4-1f2" TBG, 12.6#. 13-CR-80, V AM TOP, .0152 bpf, ID = 3.958" 4-1f2" TBG STUB I IPBTD I 17" LNR, 29#, 13·CR·80, .0371 bpf . ID := 6.184" I DATE 01/01/87 02/21/94 02/03/07 02/13/07 REV BY COMMENTS ORIGINAL COM PLETION RIG SIDETRACK N4ES RWO ?/ PJC DRLG DRAFT CORRECTIONS ST MD 5 2976 4 4509 3 5623 2 6780 1 7846 GAS LIFT MANDRaS IVD DE\! 1YÆ VLV LATCH PORT DATE 2976 0 KGB2 DMY BEK 0 02f01/07 4478 24 KGB2 DMY BK 0 02/01/07 5486 28 KGB2 DMY BK 0 02/01/07 6512 27 KGB2 DMY BK 0 02f01f07 7479 22 KGB2 DMY BK 0 02/01/07 9-5/8" MILLOUTWINDOW (11-24A) 8283' - 8328' -i4-1I2" HES X NIP. ID = 3.813' I 8521' 8545' - 7" X 4-1/2" BKR S-3 ÆRM PKR, ID = 3.870" - 4-1f2" HES X NIP, ID - 3.813' I 8608' -i 7" X 4-1 f2" UNIQUE OV ERSHOT I "'4-1/2" OTIS X NIP, 10=3.813" I 8669' "'7" X 4-1 f2" BKR S-3 PKR, ID:= 3.91" I 8689' -i4-1f2"OTISXNIP.ID=3.813" I "'4-1/2" OTIS XN NIP. ID = 3.725" I -17" MARKER JOINT (19') I -14-1/2" TUBING TAIL WLEG I H ELMD IT LOGGED 03/05/94 ?? -i FASDRILL DEBRIS ( 02103/07 RWO) I 9574' 9614' DATE PRUDHOE BAY UNIT WaL: 11-24A ÆRMIT No: 193-2040 API No: 50-029-21623-01 SEC 28. T11N. R15E 217' FSL & 180' Fa REV BY COMMENTS BP Exploration (Alaska) Well Job# Loq Description Date BL Color CD L5-25 11538589 LDL 12/28/06 1 Y-16 11626467 LDL 01/19/07 1 L-04 11603118 MEM LDL 12/30/06 1 11-24A 11638611 USIT 01/24/07 1 1-33 11631645 US IT 01/09/07 1 A-05A 11533393 USIT 01/04/07 1 DS 05-10B 11626469 SCMT 01/22/07 1 W-29 11536193 USIT 01/05/07 1 R-15A 11626266 US IT (CEMENT EVALUATION) 01/11/07 1 R-15A 11626266 USIT (CORROSION) 01/11/07 1 MPF-99 11637306 CEMENT EVALUATION/CBL 01/14/07 1 R-12 11414757 RST 09/01/06 1 1 NK-38A 40011271 OH EDIT MWD/LWD 03/11/05 3 1 NK-38A PB1 40011271 OH EDIT MWD/LWD 02/26/05 2 1 MPC-28A 11649937 MEM INJECTION PROFILE 01/05/07 1 DS 07 -04A 11533394 LDL 01/05/07 1 F-23A 11626066 lDl 01/08/07 1 P2-19 11630449 lDl 01/14/07 1 Y -09A 11630450 lDl 01/16/07 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TTN: Beth t03 -ddI PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. stANNED fES 2 1 2007 Anchorage, Alaska 99508 Date Delivered: 02/12/2007 NO. 4131 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Prudhoe Bay . . Alaska Data & Cons 2525 Gambe" Street, Anchorage, AK 99503-2838 ATTN: Beth IVE Received by: rEB 2 0 20m )CJ i~!ookª Oil JJ¡ Gi\" CQns. Commì$fJioit AnrJ'!orege :. . SARAH PALIN, GOVERNOR - AlASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 71h A VENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-24A Sundry Number: 306-382 ø~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ¡åday of December, 2006 Enc!. fJrß f z.(1¿/t tit?. ).7-.)<t)è>4/1·1ù,J I \J-l6A--/z...I,1.,/2...-o0lÞ .1'11'" STATE OF ALASKA 'þlVl~ .,þ( 8iECEIVED CAY} 111 ALA. OIL AND GAS CONSERVATION COMM.ON t APPLICATION FOR SUNDRY APPROVAL DEC 0 6 200)' 20 MC 25.280 AI;¡J:b nil o. n 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time ExtensionA-.... UUII3. (.;Ommis~· nChora"e o Alter Casing / ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended We o Change Approved Program ~ Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit Toyrill Number BP Exploration (Alaska) Inc. ~ Development o Exploratory 193-204 3. Address: D Stratigraphic o Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21623-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 11-24A / Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s}: ADL 028325 54' Prudhoe Bay Field / Prudhoe Bay Pool 1;2:t1·..·..,. ../.............;.. ......... . . .. I ... 'J,t'S. ...·Ü..J ..... ;.... ..... Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9614 9029 9574 8994 8691 None Ca¡;ina l Rnath SizR MD ,/ TVD Burst CollaDse Structural Conductor 9R' 20" 9R' 98' 1490 470 Surface 2505' 13-3/8" 2505' 2505' 3450 1950 IntRrmediate 82R3' 9-5/8" 8283' 7886' 6870 4760 Production Liner 1535' 7" R079' - 9614' 7695' - 9029' 8160 7020 Perforation Depth MD (ft); I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9213' - 9410' I 8684' - 8851' 4-112", 12.6# ./ 13Cr80 8717' Packers and SSSV Type: 7" x 4-112" Baker 'SABL-3' packer I Packers and SSSV MD (ft): 8669' 13. Attachments: 14. Well Class after proposed work: / ~ Descriptio'n Summary of Proposal o BOP Sketch o Exploratory ~ Development o Service o Detailed Operations Program /'"'. 15. Estimated Date for JanuarÁs,)007 16. Well Status after P~d work: Commencinq Operations: ~ Oil 0 Gas D Plugged o Abandoned 17. Verbal Approval: DaV o WAG 0 GINJ DWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Nam)taVid Reem Title Drilling Engineer Prepared By Name/Number: Signature Jr ß" O-A~ Phone 564-5743 Date 1t/+JDl. Terrie Hubble, 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:.Et1o - æ;.¿ D Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: ~ > t- BQPE to ~SOO , rJk. RBDMS 8Ft DEC ] S 1006 Subsequent Form Required: lO - ~. APPROVED BY Date /z,.,./3 "ð 6 Approved By: j r; -'"~ COMMISSIONER THE COMMISSION Form 1 0-403 Revised 06/2006 V V' - Submit In Duplicate on Il~/~ . . Obp G~."...,. 11-24A Rig Workover Scope of Work: Pull 4-W' completion, run and cement new 7" scab liner, run 4-W1 13Cr-80 "stacker- packer" completion. MASP: 2450 psi Well Type: Ivishak Producer Estimated Start Date: January 15, 2007 Pre-ri 0 1 S 2 E 3 F 4 0 5 0 6 re work: Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. Drift 4-1/2" chrome tubing for composite plug/chem. cutter. Pull PXN plug from tubing tail. ./ MITOA already Proposed Procedure 2 1. MIRU. ND tree. NU BOPE with 3-1/2" x 6" VBR pipe rams. Pressure test to 35 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circul ell to clean kill weight brine through the cut. 2. Pull and LD 4-W' tubing string to the cut. / 3. Set 7" retrievable bridge plug at -8150' MD. 4. Run and fully cement new 7" scab liner to -2800'md. 5. Run 4-%" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at -8530' MD. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 8. Set BPV. NO BOPE. NU and test tree. RDMO. / TREE = WELLHEAD = ACTUA TOR = KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MD = DatumlVD= 4-1/16" CrN McBlOY BAKERC 61.9' NA 3900' 37 @ 8786' 9414' 8800' SS 113-3/8" CSG, 72#, L-80, 10 = 12.347"1 Minimum 10 = 3.725" @ 8706' 4-1/2" OTIS XN NIPPLE I BKR C-2 TIEBACK SLEB/E, 10 = 7.50" 8079' 19-5/8" x 7" BKR HP A<R, 10 = 6.190" 8086' 9-5/8" X 7" BKR HMC HGR, 10 = 6.190" 8092' 19-5/8" CSG, 47#, L-80, 10 = 8.681" H 8283' I-- 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, 10 = 3.958" I 8717' 17" MARKERJT. (19') 8816' ÆRFORA TION SUMMARY REF LOG: AWS-Z-DENSILOG ON 02/17/93 ANGLEATTOPÆRF: 33@ 9210' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 2 9210 - 9213 5 05/03/98 3-3/8" 6 9213-9219 C 11/14/98 3-3/8" 6 9230 - 9235 C 01/04/06 3-3/8" 4 9264 - 9268 S 05/03/98 3-3/8" 6 9264 - 9270 C 01/04/06 3-3/8" 6 9314 - 9320 C 01/04/06 3-3/8" 6 9370 - 9390 C 03/05/94 3-3/8" 4 9390 - 9410 C 03/29/94 11-24A SAFETY NOTES: 4·1/2" CHROME T80 & 7" CHROM E LNR . 2176' 4-1/2" CAMCO, TRDP-4A, TRSSSV, 10 - 3.812" TRSV LOCKED OUT (09/05/05) GAS LIFT MANDRELS ST MD lVDDBI TYPE VLV LATCH PORT DATE 1 2995 2995 0 MMG-M DMY RK 0 08/12/06 2 5120 5033 25 MMG-M DMY RK 0 08/12/06 3 6258 6050 28 MMG-M DMY RK 0 02/22/94 4 6796 6527 27 MMG-M DMY RK 0 02/22/94 5 7381 7051 24 MMG-M DMY RK 0 02/22/94 6 7609 7260 23 MMG-M DMY RK 0 02/22/94 7 7917 7545 22 MMG-M DMY RK 0 02/22/94 8 8028 7648 22 MMG-M DMY RK 0 04/03/98 9-5/8" CSG MILLOUT WINDOW 8283' - 8328' (SECTION MILL) 8651' -14-1/2" OTIS X NIP, 10 = 3.813" 1 8669' -17" X 4-1/2" BKR SABL-3 A<R, 10 - 3.91"1 8718' 8712' -14-1/2" TUBING TAIL WLEG I H ELMO TT LOGGED 03/05/94 I I PBTD H I 7" LNR, 29#, 13-CR-80, .0371 bpf , 10 = 6.184" 1-1 DATE 01/01/87 02121/94 03/06/02 08/31/05 08/30/05 09/22/05 RBI BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK CHlTP CORRECTIONS DTRlPJC ADD TRSSSV MODEL # DAV/PJC SAFETY NOTE (FISH) DAV/PJC GLV C/O DATE 01/04/06 08/11/06 08/12/06 08/30/06 9574' 9614' ~ REV BY COMMENTS DFRlTLH PERFS DA V /PJC TRSV LOCKED OUT (9/5/05) TEL/PJC GL V C/O MSS/PAG SET PXN PLUG @ 8691' PRUDHOE BA Y UNIT WELL: 11-24A PERMIT No: 193-2040 API No: 50-029-21623-01 SEC 28, T11 N, R15E 217' FSL & 180' FEL BP Exploration (Alaska) "'·TREE= 10 4-1/16" CrN McEVOY BAKER C 61.9' NA 3900' 37 @ 8786' 9414' 8800' SS 11-24A Proposed W8..LHEAO = ACTUA TOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = Datum lVO = 113-3/8" CSG, 72#, L-80, ID = 12.347" I BKR C-2 TIEBACK SLEEVE, 10 = 7.50" 9-5/8" X 7" BKR ZXP LNER- TOP PKR 9-5/8" X 7" BKR FLEXLOK HANGER 7", 26#, L-BO BTC-M scab liner fully cemented w/15.8 ppg cl "G" cement. BKR C-2 TIEBACK SLEEVE, 10 = 7.50" 9-5/8" X 7" BKR HP PKR, 10 = 6.190" 9-5/8" X 7" BKR HMC HGR, ID = 6.190" 9-5/8" CSG, 47#, L-80, ID = 8.681" 8079' 8086' 8092' 8283' I UNQUE MACHNE OVERSHOT 14-1/2" TBG, 12.6#, 13-CR-SO, .0152 bpf, ID = 3.958" I 8717' 17" MARKER JT. (19') 8816' PERFORA TION SUMt.MRY REF LOG: AWS-Z-DENSIlOG ON 02/17/93 ANGLE AT TOP PERF: 33 @ 9210' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 2 9210 - 9213 S 05/03/98 3-3/8" 6 9213 - 9219 C 11/14/98 3-3/8" 6 9230 - 9235 C 01/04/06 3-3/8" 4 9264 - 9268 S 05/03/98 3-3/8" 6 9264 - 9270 C 01104/06 3-3/8" 6 9314 - 9320 C 01104/06 3-3/8" 6 9370 - 9390 C 03/05/94 3-3/8" 4 9390 - 9410 C 03/29/94 I -2100' H4-1/2"HESXNP,ID=3.813" I ST MD 1 2 3 4 5 6 GAS LFT MANDRB.S TYPE 4-112" x 1" valves 4-1/2" x 1" valves 4-112" x 1" valves 4-1/2" x 1" valves 4-1/2" x 1" valves 4-1/2" x 1" valves VLV DCK DMY DMY DMY DMY DMY Minimum ID = 3.725" @ 8706' 4-1/2" OTIS XN NIPPLE 4-1/2"HESXNP,ID=3.813" 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 4-1/2" HES X NIP, 10= 3.813" 8651' H4-1/2"OTlSXNIP,10=3.813" I 7" X 4-112" BKR SABL-3 PKR, ID = 3.91" 4-1/2" OTIS X NIP, 10 = 3.813" 4-112" OTIS XN NIP, 10 = 3.725" I PBTD H 17" LNR, 29#, 13-CR-SO, .0371 bpf, 10 = 6.184" I 9574' 9614' DATE 01/01/S7 02121/94 03/06/02 08/31/05 08/30/05 09/22/05 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK CHITP CORRECTIONS OTRIPJC ADD TRSSSV MODEl.. # DAV/PJC SAFETY NOTE (FISH) DAV/PJC GLV C/O DATE REV BY COMMENTS 01104/06 DFRITLH PERFS 08/11/06 DA V IPJC TRSV LOCKED OUT (9/5/05) 08/12/06 TB./PJC GLV C/O 08/30/06 MSSIPA SET PXN PLUG @ 8691' PRUDHOE BA Y UNIT W8..L: 11-24A PERMIT No: 193-2040 API No: 50-029-21623-01 SEC28, T11N, R15E21T FSL & 180' FB. BP Exploration (Alaska) . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: BP Exploration (Alaska), Inc. Katrina Cooper MB 6-2 900 East Benson Blvd. Anchorage, Alaska 99508 (908) 5644212 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 BL / EDE Disk D.S. 11 - 24a Leak Detect WLD 1 0~Sep-06 1) 2) 3) 4) 5) 6) 7) "'."(:"'; (".i;'" ~N N\r:J , ."'Ii\c},' ,. /c;3-d04 41- 1'-/ d~f..-( 8 Signed: Date : ·+!~2ß;<i:::j 'O';~~ /:~ G~;G[}:}~~tGcrnrm~~~k:D Print Name: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL :":'"A"L>j:;;;~" ~Ji,:(j),'ijEf';1ÇR'(:')G .:;c;V, WEBSITE: W'!'rf'J.),'Ef'1üi'(·''..:''3.CC);] D:\OO _ PDSANC-2006\Z _ W ord\DistributionITransnùttal_ SheelslTransnùt _ OriginaL doc RECEIVED , STATE OF ALASKA -, ALA~..} OIL AND GAS CONSERVATION COMIVi.~JION JAN 3 0 2006 .. REPORT OF SUNDRY WELL OPERATIONS ^'a k DiJ 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 rn~e~ 0 & Cas COtJä.Commis'Siol Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 A.,chorage Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development R]! Exploratory I] 193-2040 3. Address: P.O. Box 196612 Stratigraphic 'Ci Service D! 6. API Number: Anchorage, AK 99519-6612 50-029-21623-01-00 7. KB Elevation (ft): 9. Well Name and Number: 54 KB 8. Property Designation: ADL-028325 11. Present Well Condition Summary: Total Depth measured 9614 true vertical 9029.22 Effective Depth measured 9574 true vertical 8993.78 Casing Conductor Surface Production liner Length 80 2480 8259 1535 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# 13CR80 Perforation depth: Measured depth: 9213 - 9219 True Vertical depth: 8683.98 - 8689.02 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 361 3655 x 11-24A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 26 - 106 25 - 2505 24 - 8283 8079 - 9614 TVD 26 - 106 25 - 2504.95 24 - 7885.5 7695.14 - 9029.22 Burst 1490 4930 6870 8160 Collapse 470 2670 4760 7020 9230 - 9235 8698.26 - 8702.46 9264 - 9410 8726.89 - 8851.07 4-1/2" 12.6# 13CR80 23 - 8718 7" Baker HP Packer 4-1/2" Baker SABL-3 Packer 8086 8669 SC/'\N~EV: ,J¡~\N 3 1 20D5 RBDMS 8Ft JAN 3 () 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 9600 5465 0 26195 5898 0 15. Well Class after proposed work: Exploratory r Development ¡¡;¡ 16. Well Status after proposed work: Oil P' Gas r WAG r Tubing pressure 1800 2300 Service r WDSPL r GINJ r WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sharmaine Vestal _ / . \c ~ ,. / l 77-7 S,gnature'c:::::::7rLeZ.¿.~~~· ~J..~ Contact Sharmaine Vestal Form 10-404 Revised 04/2004 Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 1/26/2006 nRJhl~rAI Submit Original Only ') ) c T 11-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/3/2006 PERFORATED 9314'-9320',9264'-9270 AND 9230'-9235 WITH 3-3/8" PJ 3406, PENE 38.6", EH 0.45", 22.7 GMS. CORRELATED TO SWS USIT DATED 11 MARCH 1994. FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL TI-W, MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M PL A T T H E IS IA L U N D W E R M A R K E R C:LO~lV/DOC STATE OF ALASKA ~,.~SKA OIL AND GAS CONSERVATION COMMISSI~,, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 54' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 stratagrapic_ Anchorage, AK 99510-0360 service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 217' NSL, 180' WEL, Sec 28, T11N, R15E, UM. 11-24A At top of productive interval: 9. Permit number/approval number: 252' NSL, 2214' WEL, Sec 28, T11N, R15E, UM. 93-204 At effective depth: 10. APl number: 50-029-21623-01 At total depth: 11. Field/Pool: 530' NSL, 2489' WEL, Sec 28, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 9614 feet Plugs (measured) PBTD Tagged @ 9406' MD (5/17/98). true vertical 9029 feet Effective Depth: measured 9406 feet Junk (measured) true vertical 8848 feet Casing Length Size Cemented Measured depth True vedical depth Conductor 98' 20" 1900 Sx Poleset 98' 98' Surface 2451' 13-3/8" 2000 Sx CS III & 2505' 2505' 975 Sx PF II Production 8229' 9-5/8" 823 Sx Class G & 8283' 7886' 300 Sx CS I Liner 1535' 7" 290 Sx Class G 9614' 9029' Perforation Depth measured 9213 - 9219'; 9370 - 9410' true vertical 8684 - 8689'; 8817- 8851' Tubing (size, grade, and measured depth)4-1/2", 12.6#, 13 CE-80, Tbg @ 8718' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8669' MD; 4-1/2", Camco TRSV SSSV @ 2176' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Remesentilive Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2319 41675 2454 - 865 Subsequent to operation 1224 15865 3480 - 849 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed ~',/Y-4~ "~, ~'~,.-...-~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE-~~ 11-24A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF & PERFORATING 4/3/98: RIH & tagged bottom at 9408' MD. 4/6/98: MIRU CTU & PT equipment. RIH w/CT & loaded wellbore w/Seawater, then pumped gelled sand slurry containing 4700 lbs of 20/40 mesh sand, to isolate the lower open perforation interval located at: 9370 - 9410' MD (Z1) Ref Log: AWS Z-DENSILOG 2/17/93. Made a final top of sand plug tag at 9286' MD. POOH w/CT. RD. 418198: RIH & tagged top of sand plug at 9291' MD. 5/2/98: RIH w/bailer & dumped 3 gallons of liquid sand cap on top of sand plug. POOH w/bailer. RD. 5/3/98 - 5/4/98: A CTU Acid Wash & Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU & PT equipment. RIH w/CT & fluid packed the wellbore w/1% KCI Water, then reciprocated an acid wash across the open perforation intervals located above the sand plug at: 9210 - 9213' MD (Z2) Ref Log: AWS Z-DENSILOG 2/17/93. 9264- 9268' MD (Z2) Pumped 20 bbls NH4CI Solution w/Citric Acid @ 2 bpm, followed by 9 bbls 70% Diesel / 20% Xylene / 10% Musol, followed by 15 bbls 12% HCI w/10% Xylene & 3% Acetic Acid, followed by 10 bbls 6% HCI - .75% HF w/3% Acetic Acid, followed by 15 bbls 12% HCI w/10% Xylene & 3% Acetic Acid, followed by 40 bbls NH4CI w/Citric Acid, followed CT volume of 1% KCI Water Flush. Swapped to cement pumping 35 bbls of Latex Acid Resistive cement to squeeze off the open perforation intervals (above). Placed 5 bbls of cement behind pipe at 3350 psi max squeeze pressure & held for 1 hour. Contaminated cement w/biozan & jetted contaminated cement from well to 9285' MD. POOH w/CT. RD. 5/7/98: PT squeeze to 1000 psi w/50 psi loss in 30 minutes. 5/15/98: RIH w/CT milling BHA. Milled cement & sand plug from 9305' to 9450' MD to uncover the lower open perforation interval (above). Circulated fill from hole w/biozan. POOH w/CT. RD. 5/17/98: RIH & tagged PBTD at 9406' MD. 11/14/98: RIH w/perforating gun & shot 6' of Add Perforations at: 9213 - 9219' MD (Z2) Ref Log: AWS Z-DENSILOG Used a 3-3/8" carrier & shot the perfs at 6 spf at zero degree phasing. 2/17/93. POOH w/gun. RD. Placed the well back on production & obtained a valid welltest. AOGCC ind±vidua! Well Geological Ma~er±als Inventory Page' ! Date- 10/i© ~/95 PERmzT DATA T DATA_PLUS RUN DATE_RECVD 93-204 T 8250-9585, OH-DLL/ZDL 1 03/21/94 L 8250-9585 L 8250-9557 03/18/94 O3/la/94 93-204 ~MP/PERF L 8600-9450 i o3/18/94 93-204 ~F 93-904 GR/CCL L 82~0-95~5 L 8580-9472 L 8000-9540 1 03/18/94 1 04/27/94 1 03/18/94 93-2ua PROD S/ ~'~ GaAu/~/P L °150-9407 93~204 ~/~STVD L 8250-9585 ~o-20~= ATiC (BLUELINE L ~272~ -9390 93-204 ~T/~-P L 8845-9420 / ~o~.~ 204 ~Sl~ 93-204 -~.DL/CNL/GR/CAL L 8250-9557 01/o5/95 03/18/94 06/20/94 09/13/94 04/27/94 03/18/94 ditch samples required? yes And receive~-?--. - yes ~as the well cored~ yes '~._.~nalysis & description--received? Are well tests required~ /yes Well is in compliance initial C20MME NT S yes 1io il 0 yes no STATE OF ALASKA ALASKA '---' AND GAS CONSERVATION CC '-'./IISSION REPORT UF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 217' NSL, 180' WEL, sec. 28, T11N, R15E, UM At top of productive interval 252' NSL, 2214' WEL, Sec. 28, T11 N, R15E, UM At effective depth At total depth 530' NSL, 2489' WEL, Sec. 28, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-24A 9. Permit number/approval number 93-204 10. APl number 50 - 029-21623-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 9614 feet 9029 feet Plugs(measured) PBTD Tagged @ 9418' MD (9/10/94) Effective depth: measured 9418 feet true vertical 8858 feet Junk(measured) Casing Length Size Cemented Conductor 98' 20" 1900 # Poleset Sudace 2451' 13-3/8" 2000 sx CS III, 975 sx CS II Production 8229' 9-5/8" 823 sx G & 300 sx CS I Liner 1535' 7" 290 sx CIG Measured depth True vedicaldepth 98' 98' 2505' 2505' 8283' 7886' 9614' 9029' Perforation depth: measured 9210-9213'; 9264-9268'; 9370-9410' true vertical 8682-8684'; 8727-8731'; 8817-8851' Tubing (size, grade, and measured depth) 4-1/2", 12.6ff, 13 CR-80, Tbg @ 8718' MD RECEIVED ,~0V -'] 1994 Ai~-~ska Oil & Gas Cons. Commission Anchor~ ' Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8669' MD; 4-1/2", Camco TRSV SSSV @ 2176' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1439 20417 3723 4452 13276 1989 Tubing Pressure 389 313 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 "~¢v 06/15/88 1236/14 CC: KZ, JWP Title Sr. Op. Engineer Date "~ I ?~[ ~' U~ . SUBMIT IN DUPLICATE ~ 11-24A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/8/94: RIH & tagged PBTD at 9418' MD. 9/10/94: MIRU & PT equipment. Added perforations: 9210- 9213' MD (Z2) 9264 - 9268' MD (Z2) RIH w/perforating gun & shot 7' of add perforations as follows: Ref. Log: BHCS 2/17/93. Used a 3-3/8" carrier & shot 4' of perforations at 4 spf in the lower interval at 180 degree phasing, then PU & shot 3' of perforations at 2 spf in the upper interval. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid welltest. RECEIVED F~C)V- 'I lY9~ Gas Cons. Commission Anchor;..~ GeoQuest ~ W. International Airl~ort Road Anchorage, AK 99518-1199 ATTN.- .Shen~e NO. 8966 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 9/80/94 Field: Prudhoe Bay Well Log De~cription BL RR Sepia RF Sepia Mylar DiS. 1-7A L'l / / ^ ~.~ DUAL BURST TDT-P (9-1S-94) 1 1 D.S. 1-7A vj,~../ .._ U ~RF RECORD (9-17-94) ,, 1 1 , , .. D.S. 7-25~3m ~ ~ :PERF RECORD (9-12r94) 1 1 D.S. 9-~ ~ ~ ~ / ~ ~ STATIO PRE~URE & INJEO PROFILE (9-7-94) 1 1 D.S., 1-24A ~ -- ~. ~ ~ PERF RECORD (9-'10-94) , , D.S. 17-16 PERF REOORD (9-19-94) 1 1 ocr 05 SIGNED: / Please~jn and retum one copy Of this transmittal to Sherrie at the above address. Thank you.' DATE: GeoQuest ~ W. International Airport Road Anchorage, AK 99518-1199 A1TN: Sherfle NO. 8923 Company: Alaska 011 & ~ Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 9/12~94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar q_ ~ - ( ~ D.S. 1-6 .. . PROD PROFILE (8-20-94) 1 1 ~6- c>5 D.S. 2-13 PERF RECORD (8-21-94) 1 1 ~'-?~ D.S. 3-1 PROD PROFILE (8-19-94) 1 1 ~ D.S. 4-4 PROD PROFILE (8-25-94) 1 1 ~'~' ~'~'C D.S. 4-5A !PROD PROFILE (8-19-94) 1 1 ? ~--z.-'~____~ ~).S. 4-29 INJEO PROFILE (8-19-94) 1 1 ~e.- ?__....~_~ D.S. 6-10 PROD PROFILE (8-20-94) 1 1 2~> -~,.Z D.S. 6-15 PERF REOORD (8-20-94) 1 1 ._~ V-'5~ D.S. 9-26 LEAK DETEOTION (8-23-94) 1 1 ~ -~o'~ D.S. 11-24A DUAL BURST TDT-P (8-19-94) 1 1 ~:D.S. 11-33 DUAL BURSTTDT-P (8-25-94) 1 1 ~ - ~ ~ ! ~ ~~_y__D.S. 12-3 PERF REOORD (8-22-94) 1 1 K ' ~ ~ J ~ D.S. 14-15 PERF REOORD (8-20-94) 1 1 ~1/.....~'2 c, D.S. 14-20 PROD PROFILE (8-24-94) 1 1 S !P (~ ~' 'j ~.In.~kn ~iJ& Gas Cons SIGNED: Please ~ign and retum on/~ copy of ~is transmittal to Sherrie at the above address. Thank you. DATE: Anchorage ED Commission .... STATE OF ALASKA ALASK,~ ~ AND GAS CONSERVATION CC .41SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing , Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 217' NSL, 180' WEL, Sec. 28, T11N, R15E, UM At top of productive interval 252' NSL, 2214' WEL, Sec. 28, T11 N, R15E, UM At effective depth At total depth 530' NSL, 2489' WEL, Sec. 28, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-24A 9. Permit number/approval number 93-204 10. APl number 50 - 029-21623-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9614 feet 9029 feet Plugs(measured) PBTD Taggted @ 9498' MD (3/29/94) Effective depth: measured 9498 feet true vertical 8898 feet Junk(measured) Casing Length Size Cemented Conductor 98' 20" 1900 # Poleset Surface 2451' 13-3/8" 2000 sx CS III, 975 sx CS II Production 8229' 9-5/8" 823 sx G & 300 sx CS I Liner 1535' 7" 290 sx CIG Perforation depth: measured 9370-9410' true vertical 8763-8798' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80, Tbg @ 8718' MD Measured depth True vedicaldepth 98' 98' 2505' 2505' 8283' 7522' 9614' 9029' Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8669' MD; 4-1/2", Camco TRSV SSSV @ 2176' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 892 2383 860 1001 3447 2841 Tubing Pressure 217 242 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢._ b&~ Form 10-404 Rev 06/15/88 1166/11 cc: KZ, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 11-24A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/27/94: RIH & tagged PBTD at 9529' MD. 3/5/94: MIRU & PT equipment. Initial perforations: RIH w/perforating gun & shot 20' of initial perforations as follows: 9370 - 9390' MD (Z1) Ref. Log: Z-Densilog 2/17/93. Used a 3-3/8" carrier, & shot 6 spf, at 60 degree phasing, at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. 3/27/94: RIH & tagged PBTD at 9397' MD. 3/28/94: RIH w/CT & jetted a fill cleanout from 9400' down to 9510' MD. 3/29/94: MIRU & PT equipment. RIH w/perforating gun & shot 20' of add perforations as follows: Added perforations: 9390 - 9410' MD (Z1) Ref. Log: Z-Densilog 2/17/93. Used a 3-3/8" carrier, & shot 4 spf, at 180 degree phasing, at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production & obtained a valid welltest. RECEIVED ARCO Alaska, Inc. Date: Subject' From/Location- Telephone: To/Location: P.O. Box 100360. ~inchorage, AK Transmittal #: 94043 May 24, 1994 ARCO Static Pressure Surveys John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510.~ ~, '~0 ~5~-.'2-~ Well i Number 2-6 [ 3-32A 4-5A 6-16 1-24A Log Date (M-D-Y) 03-03-94 05-13-94 05-1 8-94 05-13-94 03-06-94 Contractor Sch Sch Static Pressure Sch Static Pressure Sch Static Pressure Sch Tool Type ! Run, i $c~e Static Pressure i 1 5" Static Pressure i 1 5" ! 15" i 1 5" i 1 5" i 1 5" i 1 5" i 15" ;~ 1 5" i 1 5" i 1 5" 16-15, j 04-01-94 i Static Pressure Sch 16-20 .,j 03-23-94 j Static Pressure 16-24 ,{ 03-24-94 ! Static Pressure 16-25 ii 03-24-94 t Static Pressure 7-09/{ 03-24-94 i Static Pressure 7-05 ,~ 03-23-94 I Static Pressure Sch Sch Sch Sch J Sch Number of Records: 11 John E. DeGrey Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil D & M Please acknowledge receipt by signing and returning a copy of transmittal. %~ka 0ii 4 6~s Co~s. AnChorage ARCO Alaska, Inc. Is a Subsidiary of Atlan~cRIchfl~tdCompany ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, A Mar 18, 1994 Transmittal #: 94032 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution =rage, AK ,, Number of Records: 7 ':"John E. DeGrey ' Well i Log Datei Number I (M-D-Y) 4-43 4-44 11-4A 1-24A 13-20 14-20 i 17-16 Tool Type i03-10-94 t . USIT- i C~ement/Corrosio i03-10-94 / USIT- · Cement/Corrosio , i 03'10'94 i '/' USIT' Cement/Corrosio i 03-11-94 1/ USiT- Cement/Corrosio i03-12-94 Inflatable Bridge /~ plu~ - 03-11-94 1-'" TDTP 03-10-94 1/ Perf record Run, Scale 1 5'1 1,5" Contractor Sch Sch 1, 5" Sch ly 5.I 1,5" 1~5" 1,5" Sch Sch Sch Sch Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ~~~~ k~ Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: ,,~ ("~z~¢'_/3 Date: 4/aska Oi/ &?as COns. ~nChorage C°'~,~is~on ARCO Alasi~ Inc. Is a Subslc~ry of AliantlcRlchfl~~ ARCO Alaska, Inc. Date' Apr 14, 1994 P.O. Box 100360, ,...norage, AK Transmittal #: 94034 Subject' ARCO Cased Hole Finals From/Location' Telephone: To/Location: John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well Number 01-09A i 77-5~ 01-11J~.! ~-17~.. 01-33 ! -'FS--f 5i 03-01 7(~-2--Lt i 03-02 · SS-~?..i 03-19 ~.-/~ ~03-29 l :.'~. 03-29 l ~q-q~.i 03-31 t i /04-43 Log Date i Tool Type (M-D-Y)! ., 04-43 i ~.04-43 04-44 04-02-94 i,," Perf Record 04-45 o5-o8 06-19 O7-O8 O7-23 09-01 09-02 03-25-94 ! TDT-P 09-03 o9-19 09-27 11-04 11-17 1-24A 12-06A 13-20 03-28-94 i/ TDT-P 03-27-94 i..,- Perf Record 03-22-94 i.- Leak Detection 03-22-94 L, Bridge Plug 03-18-94 i,/Leak Detection 03-27-94 !/ Bridge Plug 03-27-94 i."" Bridge Plug 03-29-94 ! / TDT-P Run, Scale 17 511 1,5" 17 511 , 5II , 2I' ! 5II , 5II ! 5II ! 5II 1~ 5II Contractor Sch Sch Sch Sch Sch ¢ Sch Sch Sch Sch Sch 03-29-94 i/ CNTG 1 5" Sch o3-1o-94 i ¢' USIT Sch Sch 03-13-94 ~v' USIT 03-29-94 / USIT Cement 1 5" 1 5" 1 5" 1 5" 1 5" " 1 5" 1 5" Sch 03-14-94 1-/ Prod Profile Sch 03-18-94 i,/ Perf Record Sch · 04-03-94 i-- Perf Record Sch · Sch 1, 1"&5" Sch ~ 1, 5" Sch 03-21-94.!,/ Bridge Plug 03-30-94 i,,' Prod Profile · 03-17-94 i./ Prod Profile · 03-29-94 i./ Prod Log 04-01-94 !¢' Perf Record 03-16-94 i/ Prod Log 03-22-94 i / Perf Record 03-16-94 1,/ Patch setting 03-29-94 i-/ Perf Record 1, 1"&5" ! 5II 1~, 5'1 ! 5II Sch Sch Sch 1, 5" Sch 1, 5" Sch Sch 03-18-94 i.- Prod Profile 1, 1"&5" Sch 03-15-94 i." Leak Detection 1, 1"&5" Sch "~ .--5~, 14-03 03-28-94 i - CNL 1,5" Sch 14-23 03-19-94 ! / Prod Profile 1, 1"&5" Sch 03-15-94 !,/Leak Detection 03-28-94 i¢ Patch Settincj 03-21-94 i--' Bridge Plug 03-17-94 !,," CNL 03-15-94 i,,.-- Perf Record 03-14-94 i,-" Leak Detection 03-14-94 1 ¢ Perf Record I f 5II ! 5II .. 1,5" ~ 1, 5" 1, 2"&5" ! , 5" .. 1 1,5" 03-20-94 i¢ TDT-P !/14-28 ~L-I 7_~14-28 14-28 · ~5-1~ 14-35 ~2.-t 5~! 16-04A 16-18 6-28 8-08 Sch Sch Sch Sch i Sch i Sch i Sch } Sch Number of Records: 38 ARCO AlasKa, inc. i; a Subsidiary of AflanflcRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] S~ [] ABANDONED [] SERVICE [] _ 2. Name of Operator 7. Permit Number 0 RIG INA L P. O. Box 196612, Anchora~le, Alaska 99519-6612 5 o- 029-21623-01 4. Location of well at sudace 9. Unil or Lease Name 217' NSL, 180' WEL, SEC. 28, T11N, R15E;;7-: Prudhoe Bay Unit At Top Producing Interval ,! ....... >,¢-,.-~'~ 10. Well Number At Total Depth ~ V:;:;;p'i;!i ) . ~ ..::~..t~ 11. Field and Pool 530' NSL, 2489' WEL, SEC. 28, T11N, R15E /~ '-...i: :.', -'~ ~~ -- Prudhoe Bay Fiold/Prudhoo Bay Pool . . 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 54' J ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, il otfshore 116. No. of Completions 2/14/94 1/16/94 3/5/94I N/A feet MSL J' One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey J20. Depth where SSSV set J2.1. Thickness of Permafrost 9614'MD/9029' TVD 9574'MD/8994' TVD YeS [] NO []I 2176' feet MD !' 1900'(Approx.) 22. Type Electric or Olher Logs Run GR/ZDL/CNL/DL L/M WD 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SLZE VVT. PER FT. GRADE TOP BO'I'rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 98' 30" 1900 # Poleset (Approx.) 13-3/8" 68#/72# K-55/L-80 Surface 2505' 17-1/2" 2ooo sx cs//J/4oo sx cs/~575 sx cs I/ 9-5/8" 47# L-80 Surface 8283' 12-1/4" 823 sx "G"/300 sx CS I 7" 29# NT80/NT13CR 8079' 9614' 8-1/2" 290 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and ;>5. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD/ PACKER SET (MD/ Gun Diameter 3-3/8" MD TVD (Subsea) 4-1/2", 13CR80 8718' 8669' 9370'-9390' 8763'-8780' 6 spf 9390'-9410' 8781'-8798' 4 spf 26. ACID, FRACTURE, CEMENT SQUEFTE, ETC. DEPTH INTERVAL (MD} AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 3/7/94 J Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL ,.%AS-MCF WATER-BBL CHOKE,SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OlL-BBL GAS-MCF WATER-BBL !OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ol oil, gas or water. Submit core chips. RECEIVED APR 1 b 19~4 Ai~.oka Oil 8, ~as Cons. Commission gnchorago Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOL~ MARKERS ~ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Shublik 8840' 8323' Top Sadlerochit 8882' 8356' Zone 3 9046' 8490' Base Sadlerochit 9415' 8801' RECEIVED APR 1 5 199~ /~,!aska 0il & Gas Cons. Commission Anchorage '31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. _ ~ Title DrillingEngineerS{/.oerv/~j(~r Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIO~ PAGE: 1 WELL: DS 11-24A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50'- PERMIT: APPROVAL: ACCEPT: 02/09/94 04:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 02/09/94 ( 1) TD: 9535 PB: 9380 02/10/94 ( 2) TD: 9535 PB: 8682 02/11/94 ( 3) TD: 9535 PB: 8682 02/12/94 ( 4) TD: 9535 PB: 8682 PREPARE TO CIRC OUT FRZ PROT. MW: 8.5 Seawater PREP RIG. LD DERRICK. MOVE RIG TO DS 11-24A. RAISE DERRICK. SPOT OVER WELL AND ACCEPT RIG AT 04:00 HOURS ON 2/9/94. R/U ON WELL. TAKE ON SEAWATER. R/U LUBRICATOR AND PULL BPV. PREPARE TO CIRC OUT FREEZE PROTECTION. PULL & LAY DOWN 5.5" TBG MW: 8.5 Seawater SPOT OUTSIDE TANKS. RU ON TREE TO DISPLACE. CIRC OUT FREEZE PROTECTION FLUID FROM TBG. AND ANNULUS. CIRC. NO GAS DURING OBSERVATION.SET BPV. ND TREE AND ADAPTER FLANGE. WORK ON TIGHT LOCK DOWN SCREWS AND NU BOP'S. CHANGE TOP RAMS TO 5" AND TEST BOPE. RU LUBRICATOR, PULL BPV. PULL TBG TO FLOOR. L/D LANDING JT AND HANGER. CBU 80 SPM AT 500PSI. TOOH LAYING DOWN 5.5" TUBING AND COMPLETION JEWELRY. TIH W/SECT. MILL P/U PIPE MW: 8.5 Seawater SERVICE THE RIG. TRIP OUT L/D 5.5" L/80 TBG. 205 JTS. 11 GLMS, 1 PUP AND 19' CUT OFF. PU 9-5/8" BAKER PACKER AND 6.75" DCS. SET STORM PKR AT 180'. ND BOPS AND TBG SPOOL. REPLACE TBG SPOOL, PACKOFF AND SLIP RUBBER SEAL. TEST PACKOFF TO 3500PSI. NU BOPS. TRIP IN AND RETRIEVE STORM PACKER. TEST TOP BOTTOM AND SHEAR RAMS TO 5000PSI. INSTALL WEAR RING, MU SERVCO SECTION MILL AND PU 17 JTS HWDP TIH PICKING UP 5" DP MILLING WINDOW MW: 9.9 KC1 TIH W/ SECTION MILL PICKING UP 5" DP. WORK ON PUMP, DISPLACE SEAWATER WITH KCL MUD. WAIT ON VAC TRUCK TO TRANSFER MUD. (PHASE 3 CONDITIONS) SPOT 18 PPG. HI/VIS PILL ON BOTTOM. LD 8 JTS DP. TEST 9-5/8" CSG. TO 2750PSI F/30MIN. MILL WINDOW F. 8283 T/8318 RECEIVED APR 1 3 1994 Oil & Gas Cons. Commission Anchorage ~ELL - DS 11-24 OPERATION: RIG : DOYON 16 PAGE: 2 02/13/94 ( 5) TD: 9535 PB: 8682 02/14/94 ( 6) TD: 8370' (8370) 02/15/94 ( 7) TD: 8828' ( 458) 02/16/94 ( 8) TD: 9290' ( 462) 02/17/94 ( 9) TD: 9614' ( 324) 02/18/94 (10) TD: 9614' ( 0) TESTING BOP TOP & BOT. MW: 9. 9 KC1 CLEAN FLOW LINE. MILL F/8283 T/8328. CIRC HOLE W/ HI/LO SWEEP AND JET FLOW LINE. LD MILL PU MIXING SUB ON OPEN ENDED DP. TIH CIRC WHILE BJ BATCH UP. CMT W/ 5 BBLS H20 AND TEST. PULL 12 STNDS UP CIRC DP VOLUME. TRIP OUT LD EXCESS DP. JET BOPE FOR METAL CUTTINGS. CHANGE RAMS T/ 3.5 X 6" TOP AND 4.5 X 7" BOTTOM. TEST BOPE TOP AND BOTTOM. DIRECTIONAL DRLG MW: 9.9 VIS: 47 TEST BOPE UPPER AND LOWER RAMS. INSTALL WEAR BUSHING. MU MUD MOTOR FILL PIPE AT 3516, 6295. CIRC 5 MIN. ON EACH FILL. LD 12 JTS. DP. KELLY UP AT 8065 AND BREAK CIRC. WASH TO TOP OF CMT. AT 8103. DRILL CMT F/8103 T/8283. DIRECTIONAL DRILLING F/8283 T/8370. CIRC FOR TRIP MW: 9.8 VIS: 40 DIRECTIONAL DRILLING F/8370 T/8581. CBU. TOOH TO SHOE. CLEAN PITS AND CHANGE OVER TO NEW MUD. DISPLACE HOLE TO NEW MUD. TIH TO BOTTOM. PU KELLY AND BREAK CIRC. DIRECTIONAL DRILLING W/MOTOR F/8581 T/8828. CBU FOR TRIP. DRILLING MW: 9.9 VIS: 45 TOOH. LD MOTOR AND MWD TOOLS. PU LOCKED ASSY AND TIH W/BIT # 2. PACK HOLE ASSY AND FILL AT 3466, 6585 AND 8207. REAM F/8730 T/8828. DRILL FROM 8828 TO 9290. TRIP OUT AT 9614 SLM MW: 9.8 VIS: 45 DRILL F/ 9290 T/ 96145. (LOST 100 BBLS OF MUD) CIRC AND CONDITION HOLE AND MUD. SHORT TRIP TO SHOE. OK. MIX AND SPOT LCM PILL ON BOTTOM. TRIP OUT TO RUN LOG. DROP MULTI-SHOT AND SLM. RU T/RUN 7" LINER MW: 9.8 VIS: 47 TRIP OUT TO LOG. SLM AND MULTI-SHOT W/S. SUN (SLM NO CORR) RU ATLAS WL TO LOG 8.5" OPEN HOLE. RUN #1 GR/ZDL/CN/DLL TO 9599' WLM. RD ATLAS. PULL WEAR BUSHING AND TEST BOPE. STATE WAIVED TEST. TIH CIRC AND RECIP. NO FLUID LOSS. HEAVY CRUDE W/BTTMS UP. TRIP OUT. LD BHA. RU TO RUN 7" 29# LINER. RECEIVED APR 1 5 1994 /,..i~.$ka Oil & 6as Cons. Commission Anchorage ~WELL : DS 11-24 OPERATION: RIG : DOYON 16 PAGE: 3 02/19/94 (11) TD: 9614 PB: 0 02/20/94 (12) TD: 9614 PB: 9547 02/21/94 (13) TD: 9614 PB: 9547 02/22/94 (14) TD: 9614 PB: 9547 PU 6" DRILLING ASSY MW: 0.0 KCl RU TO RUN 7" 29# LINER. PU BAKER LINER HANGER. 1 STD 5" DP. CIRC PIPE VOLUME. TIH W/LINER TO 9-5/8" SHOE AT 8283. CIRC AND CHK WTS. TIH TO BOTTOM THRU OPEN HOLE. CIRC AND RECIP LINER F/ 9584 T/9614. PREPARE TO CMT. W/20 BBLS 2% KCL, 72 BBLS MCS-4 AT llPPG. FOLLOWED BY 59.5 BBLS CMT AT 15.7 PPG. DISPLACED W/5 BBLS H20 193 BBLS MUD. CIP AT 21":30 HOURS. SET HNGR. W/3000 PSI PACKER W/4500PSI. RELEASE LINER, REVERSE OUT. TRIP OUT. LD LINER TOOL. CUT DRILLING LINE. PU 6" DRILLING ASSY. RUNNING 4.5" TBG MW: 8.5 Seawater PU 3.5" DP TIH. TAG TOP OF LINER AT 8079. RIH TAG CMT AT 9545. DRILL CMT F/9545 TO LNDG COLLAR AT 9574. CIRC HOLE CLEAN. DISPLACE W/SEAWATER. TEST CSG TO 3500 PSI 30MIN OK. STAND BACK 50 STDS 5" DP. LD REMAINING STRING. RU WEATHERFORD & RUN 4.5" CR-13 12.6# TBG. TRYING TO SHEAR RP VALVE MW: 8.5 Seawater CONTINUE RUNNING 4.5" CR13 12.6# COMPLETION STRING. RU CONTROL LINE UNIT, CONNECT TO SSSV, TEST TO 5000PSI. MU HANGER TIE-IN CONTROL LINE AND TEST. PU LANDING JT, DROP BAR AND INSTALL BPV AND LAND TBG. ND BOPE, ADAPTER FLANGE AND TREE. PRESSURE TEST TBG. TO 4000PSI. AND SET PACKER. TEST ANNULUS TO 3500 PSI W/1500PSI ON TBG. (TEST 30 MIN EA.). ATTEMTING TO SHEAR RP VALVE IN TOP GLM. W/3500PSI. NO SUCCESS. WAIT ON WL UNIT TO RETRIEVE RP VALVE. RIG RELEASED AT 15:00 HRS MW: 8.5 Seawater ATTEMPT TO SHEAR RP VALVE. CALL OTIS FOR WL. RU OTIS, RIH. FOUND FLAPPER VALVE CLOSED. POOH W/WL. PRESS. TBG TO 4200PSI. CONTROL LINE TO 6000. VALVE OPENED. BLED PRESSUE. PRESSURE ANNULUS TO 3000 PSI. SHEAR RP VALVE. DISPLACE 140 BBLS. DIESEL TO WELL ANNULUS. U-TUBE DIESEL TO TBG. INSTALL BPV. CLEAN UP AND PREPARE TO MOVE. RIG RELEASED FROM DSll-24A AT 15:00 HOURS ON 2/21/94. SIGNATURE: (drilling-superintendent) DATE: RECEIVED AP[R '1 5 1994 ~,'~-~"~ Oil & Oas Cons. Oommission Anchorage ORIGINAL WELL. ~,&'~ ~&4Ti.Of~: LAT(t'V-S) 0.00 Ti~. IN F'Oi~;~(TIP) : ~T!TdD~(N/-S) 7682,50 -128.97 -1817,07 I)~'(~-W) 0.00 317,75 RECEIVED ,z~,l:~iR '1 5 1994 Alaska Oil & Gas Corfs. Commission Anchorage ~.~;ED IhT~VAL L~TiC~ T~q~ET ~ATIOH ~I~ ~Ti~ODE D~ D~TH ~IOH I~, ft ft ft ft d~ deg ft ~280,00 0.0 7882,50 1126.Z~ ~,~ 2~,~ -12~,?7 8523,3~ 31,6 8107,18 1~3,~) 24,~ 310,50 8~, ~o 31.8 8137.~ 12t6.75 26.10 310.67 85M.~ ~.6 8164.32 1~.07 27.73 313.~ -80.~ D~'~,TURE DISP~ at AZIMUTH it ft deg -1817.07 1821.~4 265.74 -1~7.74 1890.92 266.78 -1~.~ 1900o4? 267.03 -1908.24 1710.34 267.31 -1918.18 1919o87 267.59 de~/ 0.00 6.43 5,5I ~14.98 8708,96 0736°02 ~J,2 819O.62 124~.55 29.72 314.47 31.2 82t7.63 12~..~ 31.49 315.04 -59.34 31.7 824~.36 1277.40 ~3,¢E, 317.98 -~..OO 31.1 8270.06 12~4.97 35.36 318.% -1~8.63 192~.92 267.71 -173~?.89 1940.80 268,25 -1~51.59 1~2.15 2~.62 -19(J,~ 19~.~ 26%01 -1974.~ I~74.79 269.~ 5.78 7.~ 6.~ 4.24 29.6 8317,~ 1330,13 36.56 317.~ -7,27 1986.30 ~69,.79 3.62 ~ 'ON 2~/d ~,~ ,~. i~ ~,~ ~ii~. C~- I_RAT~ ~_~H~ [~'~.~i_CHG TUFJ'~_RAI~. CLDSL~ TOOL_FACE DLS DL~T ft ft deg deg deg/lOOft deg deg de~/lOOft ft deg de~/l(~t deg/lOOft**2 82S0,0 7g~2,50 0,00 0,00 8471,8 8:x~.0,20 2,6! 2.61 8523,4 8109.18 1,40 4.0I 8~ ~ ~t°~,~5 1,75 5,76 85~4,8 8164.32 1,63 7.~' 0,00 0,00 0,00 1,23 ~,85 36,8~ 4,41 5,32 42,18 5JO 0,18 42,~ 5,49 2.6& 45,04 0,00 143i,74 0,00 0,00 0,00 17,40 14E4,86 ?6,6? 6.43 3,04 16,83 1471,03 59,2? 8,06 5,15 0,56 1472,72 2.73 5.51 6,03 9,07 0,00 0,00 6,86 4,56 ~15,0 8190,82 1,?? 9,38 8~;.~ 6217.63 1,76 I1.15 8677,8 8244,36 1,77 13,12 87(~,0 8270,06 1,~ 15,02 8738,8 82?4,23 1,1~ 16,21 6,59' 1.11 46,15 5,70 0,57 46,72 6,20 2.94 6,11 0,98 50,64 3,?? 0,72 51,36 3.6? 147~.02 15.54 6.82 0,12 1.83 1475,84 9,53 5,78 3,34 9,2~. 1476,20 40,01 7.95 6,87 3,I5 1475,98 16,67 6,36 5,11 2,41 1474,05 37,97 4.24 7,11 6766.4 8317.99 0,01 16.22 0.02 -1.80 49,56 -6,08 1475,18 ?0,34 3,62 2,08 SPErRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 PRUDHOE BAY DRILLING PBU/ll-24A ORIGIkt ,L NORTH SLOPE - COMPUTATION DATE: 2/28/94 ELECTRONIC MULTI.SHOT SURVEY JOB NUMBER: AK-EI-40016 KELLY BUSHING ELEV. = 53.80 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8280 7883.00 7829.20 20 20 8321 7921.53 7867.73 19 37 8414 8008.80 7955.00 21 12 8507 8094.97 8041.17 23 3 8600 8178.84 8125.04 28 10 S 88.32 W .00 129.009 1817.00W 1125.95 N 86.63 W 4.55 128.809 1831.00W 1135.51 N 65.75 W 7.97 120.979 1861.97W 1162.13 N 56.27 W 4.32 103.949 1892.47W 1195.24 N 46.37 W 7.15 78.659 1923.55W 1234.86 8693 8258.55 8204.75 33 46 N 43.28 W 6.26 44.659 1957.19W 1282.64 8786 8334.47 8280.67 36 46 N 43.45 W 3.23 5.619 1994.06W 1336.33 8879 8409.19 8355.39 36 18 N 45.66 W 1.50 33.84N 2032.90W 1391.65 8972 8484.66 8430.86 35 11 N 45.75 W 1.19 71.79N 2071.79W 1445.88 9065 8561.06 8507.26 34 19 N 45.99 W .95 108.71N 2109.84W 1498.79 9158 8638.26 8584.46 33 27 N 45.65 W .95 144.84N 2147.03W 1550.55 9251 8716.23 8662.43 32 35 N 45.79 W .93 180.23N 2183.32W 1601.15 9344 8794.98 8741.18 31 39 N 45.38 W 1.04 214.84N 2218.65W 1650.52 9437 ~8874.55 8820.75 30 41 N 44.87 W 1.08 248.80N 2252.76W 1698.59 9530 8955.31 8901.51 28 48 N 40.57 W 3.06 282.65N 2284.08W 1744.70 9574 8994.07 8940.27 27 37 N 38.95 W 3.19 298.63N 2297.39W 1765.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2316.72 FEET AT NORTH 82 DEG. 35 MIN. WEST AT MD = 9574 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 317.76 DEG. RECEIVED APF? '1 3 1994 ~chorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/ll-24A 500292162301 NORTH SLOPE COMPUTATION DATE: 2/28/94 JOB NUMBER: AK-Ei-40016 KELLY BUSHING ELEV. = 53.80 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8280 7883.00 7829.20 9280 8740.66 8686.86 9574 8994.07 8940.27 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 129.00 S 1817.00 W 397.00 191.13 N 2194.52 W 539.34 142.34 298.63 N 2297.39 W 579.93 40.58 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE~u{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/ll-24A 500292162301 NORTH SLOPE COMPUTATION DATE: 2/28/94 JOB NUMBER: AK-Ei-40016 KELLY BUSHING ELEV. = 53.80 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8280 7883.00 7829.20 129.00 S 1817.00 W 397.00 8355 7953.80 7900.00 127.26 S 1842.48 W 401.49 4.49 8462 8053.80 8000.00 112.89 S 1877.90 W 408.62 7.13 8571 8153.80 8100.00 87.31 S 1913.99 W 418.03 9.41 8687 8253.80 8200.00 46.90 S 1955.05 W 433.52 15.49 8810 8353.80 8300.00 4.88 N 2004.00 W 456.34 22.81 8934 8453.80 8400.00 56.57 N 2056.17 W 480.42 24.08 9056 8553.80 8500.00 105.26 N 2106.28 W 502.41 21.99 9176 8653.80 8600.00 152.02 N 2154.38 W 522.83 20.42 9295 8753.80 8700.00 196.97 N 2200.51 W 541.78 18.95 9412 8853.80 8800.00 240.07 N 2244.07 W 559.07 17.29 9528 8953.80 8900.00 282.02 N 2283.53 W 574.48 15.41 9560 8981.67 8927.87 293.58 N 2293.31 W 578.33 3.85 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, inc. Date: Subject: From/Location: Telephone: To/Location: P.O. 100360, Anchorage, AK 99510 Mar 17, 1994 Transmittal #: ARCO Open hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94031 .~I 18-23A ! 11-06-93 18'23A! 12'21'93~ i Well iLog Datei Tape Type Number (M-D-Y) .~ i 11-24Ai 2-17-94 ! 15-09AI 11-30-93 i Run, Footage i'DLL/ZDL/CN/GR i (~8250- MWD/GR (,~9971- /-~:~1 , O {"(- 8767 MWD/GR 1 (:~' 9635- f.00c~ O1'{ 7999 ASCIi TO LDWG i('~ 10404- ~0c.,_~ CONV[~ 9320 Contractor Atlas SCH SCH SCH Number of Records: 4 DeGrey Distribution: Bob Ocanas BPX · .~State:~of~AI as~a. Phillips Exxon Please ackngwledge receipt by signing and returning a copy of transmittal. ARCO Alaska, inc. Date: Subject: From/Location: Telephone: To/Location: P.O. x 100360, Anchorage, AK 99510 Mar 15, 1994 Transmittal #: ARCO Open Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94028 t Well i ,Number ~{~-'tO ~/04-44 N, O4-44 q q-{~"5 !//04-47 ~ 04-47 ~ 04-47 i ~,,04-47 ~ ~-?.,Oq i/11-24A t~' 'I1'24A 1-24A [ 11-24A i\11-24A cf~[~ 1/15-07A i . ~_ 15-07A ~ 15-07A i ~ 1 '~5'07A ~tl~ I 15-09h Number of Records:16 Uohn E. DeGrey Log Date! Tool Type i Run, Scale j Contractor i (M'D'Y)l 3-05-94 I MWD/DGR/EWR ~IYl, 27511 Sperry-Sun 3-05-94 ! MWD/DGR/EWR ~91, 2'&5 Sperry-Sun 1-26-94 ~ BHC Ac~us/GR ! 1, 2"&5" Atlas 2-17-94 CDuai LateroloCGR! 1, 2"&5" Atlas 2-17-94 ~ Borehole/Profile [ 1, 5" Atlas 2-17-94 ~ CNUGR ~ 1, 2"&5" Atlas 2-20-94 ~ MW~G~~¢ ~, 2"&5"~' ~Sperw-Sun ~ ~ 2-20-~4 MW~/D~~ ~ ~, 2"&5" ~Sper~-Sun Distribution: Central Files Phillips ANO-8 Geology BPX Exxon ~? Mobil D & M PB Well Files P1 Files Please acknowledge receipt by signing and returning a copy of transmittal. By: _ _. (/"'~ Date: t E('EIVED MAR 7 8 1994 Alaska Oil & Gas Cons. Commission Anchor.-~e ARCO Alasi(a. Inc. I$ a Sub~ldla'y of A~anficRIchfle~dCon~ ARCO Alaska, Inc. Date- Subject: From/Location: Telephone: To/Location: P.O. Box 100360, '-'chorage, AK Mar 15, 1994 Transmittal #: 94029 John E. DeGrey/ATO-1529 (907) 263'4310 · Distribution m- m i 0~-02 1 3e---'i~' i Ol-O3 i ~-i~b ( 01-09 ! or"+.--iSt I 01-111 · '+-e,-- f'z.~ i o'1-18! t~ i o'1 25 I ~'z.-, 5~ - . cJ%..-, lq."+ j,/O3-20A ! .., I KO3-20A ! 'e,..t-p, crt. i 03-32I ,'z..'- ~t% i 03-34A i --4.-o4H-'Z. ! 04-01 i %\- Well iLog Date · Number! (M-D-Y) 04-24 04-40 ! 0~-~6 ~ V04'47 i ~04-47 ! %04-47 o5-o~ ) 05-14A 2-26-94 2-19-94 3-01-94 2-27-94 2-23-94 3-06-94 2-17-94 3-03-94 2-26-94 2-24-94 2-19-94 2-22-94 2-22-94 2-16-94 2-18-94 '2-15-94 2-15-94 2-11-94 7-11-93 Tool Type Run, Scale i Prod/Spin/Temp I~ ) Prod~BS/Temp Tubing Cutter Prod Prof/Spin ! Leak Detection l 1, Contractor 1, 5" Schlumber 1, 5" Schlumber ! 5II CNL [ 1, 5" Perf i 1, 5" Dual Burst 1'¢-t'~ 1, 5" Leak/Press/Temp,,i Prod/Press/Tempi Prod 1 5" Schlumber Prod Perf ) v Rope Perf ) Perf i '/CBT-GR ! 1 v CET-GR i 1 1, 5" Schlumber 1 "& 5" Schlumber Schlumber Schlumber Perf i 1 USiT/Cem&Corr (b8,¢~1 Schlumber 1, 2" Schlumber 1, 2"&5" Schlumber 1 5" 1 5" I 5" 1 5" 5" 5" 5" 5" Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber 05-15A i 05-26 06-15 06-22A 07-08 07-23 09-34 11-02 1-04 11-7ST 16ST 11- 6ST 1-17 ~(~- 11-23 1-24A 11-24A 05-15A ~ 3-02-94 Dual Burst 2-21-94 Prod I 2-22-94 Neutron 3-01-94 Perf 3-02-94 Prod 3-07-94 Leak/S 2-21-94 Cutter 2-10-94 2-20-94 Cutter 2-17-94 Tubir 3-06-94 2-25-94 Leak/Press/Temp /S 3-08-94 Comp/l~l~[table 2-20-94 Leak 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" ! 5II 5" 1 5" 1, 1"&5" Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber 1, 5" Schlumber I ZoCo-.- 1, 5" Schlumber 3-08-94 Prod 1, 5" Schlumber 8-09-91 TMD 1, 5" Halliburton 3-05-94 Perf/GR/CCL 1, 5" Schlumber 2-22-94 Comp/Perf 1, 5" Schlumber ARCO Alaska, Inc. is a Sub~lar~ of At~antlcRlchfleldComll3y 12-01 i 3-06-94 J Prod 13-10 i 2-24-94I Perf 14-2B i 1-16-94 I CNL/GR ! 1, 2"&5" 14-2B f 1-16-94 14-2B ! 1-16-94 14-2B f 1-16-94 i Dual Lateriog/GRl 14-2B i i Se~] Bond/GRIc¢ 14-2B I 1-23-94 i PFC/GR/CCL .14-2B i 1-23-94t PFC/Collar 1-19-94 Sub-Sea i BH~ Acoustilog ~/4¢- 1, 1"&5" $chlumber 1, 5" Schlumber Schlumber 1, 1"&2" Schlumber 1, 2"&5" Schlumber ~ 1, 5" Schlumber I... 1, 5" Schlumber PWDW 02-01 1, 5" Schlumber 1, 5" Schlumber 4-24 i 2-19-94 t Lea~. 1, 5" 4-28 ! 3-05-94 t_ Leak 1, 1"&5" 4-34 i 2-15-94 I Prod/Press/Temp 1, 2"&5" 6-08I 3-07-94 I Prod Prof/Spin 1, 2"&5" 7-21 . 2-24-94 i Pelf 1, 2"&5" i2-09-941 Water 1,5" Inj/FBS/TempI~ Well 4-24 the correct APl # is 50-029-21508-00 Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber Number of Records: eGrey Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ,State'0f Alaska ~ Mobil _. Please acknowledge receipt by signing and retuming a copy of transmittal. By: .4/~.~ 1~-.) ~~ Date: RECEIVED ALASKA OIL AND 6AS CONSERVA~'ION CO~I~iiSSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 12, 1994 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 11-24A ARCO Alaska, Inc. Permit No. 93-204 Sur. Loc. 217'NSL, 180'WEL, sec. 28, TllN, R15E, UM Btmnhole Loc. 501'NSL, 2487'WEL, Sec. 28, TllN, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. , Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillEillb. Type of well. Exploratory[] Stratigraphic Test[] Development Oil[ii Re-Entry [] DeepenBI Service [] D, evelopment Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 54' feet Prudhoe Bay Field/Prudhoe 13. Address 6.' Property Designation Bay Pool P. 0. Box 196612. Anchorage. Alaska 99519-6612 ADL 28325 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ,,Ac 25.025) 217' NSL, 180' WEL, SEC. 28, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 443' NSL, 2427' WE/_, SEC. 28, T11N, R15E 11-24A U-630610 At total depth 9. Approximate spud date Amount 501' /,:SL, 2487' WEL, SEC. 28, T11N, R15E 1/15/94 $200,000.00 12. DiStance to near'est 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa,dTVD) property line ADL 28326-2791' feet No close approach feet 2560 9575' MD/8998' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.o35 (e)(2)) Kickoff depth 8300 feet Maximum hole angle32, z¢o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing- Weight Grade Coupling Length MD TVD MD TVD (include-stage data) 8-1/2" 7" 29# 130R8O NSCC 1275' 8150' 7703' 9575' 8998' 250 sx Class "G" ,.._ .N, h_.Lt: I v 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 0~.0 Total depth' measured 9535 feet Plugs (measured) true vertical 9021 feet h.i~,.,.-;k~ UII & Gas Cons. C0mmission~ Effective depth: measured 9474 feet Junk (measured) Anchorage, true vertical 8966 feet Casing Length Size Cemented Measured depth True Vert;cal depth Structural Conductor 98' 20" 1900 # Poleset 98' 98' Surface 2447' 13-3/8" 2000 sx CS !11 & 2505' 2505' Intermediate 975 sx CS il P rod uction 9459' 9-5/8" 823 sx "G" & 9517' 9005' L i n e r 300 sx CS I Perforation depth: measured 9336'-9366' true vertical 8842'-8868' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drillin9 fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby c_~rtify that th,e foregoing is true and correct to the best of my knowledge Signed ~'~.-.4 ./.~~ /~r- 7"¢??',V ,~r~¢v~ Title Drilling Engineer Supervisor Da',e , ~ Commission Use Only Permit ~umber IAPI number___,? ~.~__ ~-~--_~ ,, IApproval date _ See cover letter 0- _.¥_: .... r i-' ~ Ifor other requi, aments Co,:';:itions of appro~,al Sam~?. required [] Yes [] No Mud Icg required LIYes ,i~' No Hydrogen sulfide measures [] Yes J~ No Directional survey required ~ Yes [] NO Required working pressure for BOPE 1-12,,4; I-]3M' 1~5M; I-I10M' I-]15M; Other: Original Signed By by order of Approved by rlm~irl W .lnhn~tnn Commissioner tne commission Form 10-401 Rev. Submit in plicate I Well Name: IDS 11-24A Redrill Plan Summary IType of Redrill (producer or injector): I Producer Surface Location: Target Location: 'Bottom Hole Location: 217 FSL 180 FEL S28 T11N R15E UM 443 FSL 2427 FEL S28 T11N R15E UM 501 FSL 2487 FEL S28 T11N R15E UM [AFENumber: [4J8018 ] [ Estimated Start Date:- [ 01/15/94 [MD- 19575 [Rig: [Doyon#16 [ Operating days to complete: I 14 I TVD: [8998' ss ! [KBE: [54' Well Design (conventional, slimhole, etc.): _ · ]conventional Objective: Twin sidetrack well. Severe tubing corrosion has made the existing wellbore non producible. Sidetrack well will provide wellbore to recover reserves targeted to the original DS 11-24 well. Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. Special design considerations [none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30 m i n ( % ) ( % ) ,,, KOP' 9.5 10 15 5 10 10 0 5 to tO tO tO to to to tO tO TD' 10.d 18 30 15 30 5 I 0 8 Directional: I KOP: 18300 MD I [ Maximum Hole Angle: [ 32.76 de~ees Close Approach Well: NONE The above listed wells will be secured during the close approach. RECEIVED Redrill Plan Summary DEC 2 8 ]993 oil & Gas Cons. Commission Anchora. qe Page 1 Casing/Tubin~ Pro~ ram: Wt/Ft Hole Siz~ Csg/ ' Wt/Ft~ Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29# 13CR80 NSCC 1275 8150/7703 9575/8998 Cement Calculations: ] Liner Size: I Basis:! 50~o open hole ex~ess, 80' shoe joint, 150' liner lap and 150' excess above line]' with DP. ,, Total Cement Volume: 250 sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. RECEIVEE) DEC 2 g '~99b bi[ & Gas 6ons. 6ommission Anchorage Redrill Plan Summary Page 2 Objective_: The primary objective is to return the Lower Romeo to Iow GOR production. This work is necessary to repair corroded tubing and abandon the top production interval. Six GSO squeezes have been completed in an attempt to shut off gas from the top interval. The PI of the Lower Romeo sands should be sufficient to withstand conventional drilling techniques. The expected post sidetrack production is 1100 BOPD with 40% WC and 150O GOR. ¢¢ope: 1) P & A existing well per state regulations. 2) Pull existing 5 1/2" tubing. 3) Mill window in 9 5/8" casing. 4) Set kickoff plug and drill 8 1/2" hole 5) Run full suite of OH logs, GR/DLL/BHCS/CNL. 6) Cement 7" liner in place. 7) Run 4-1/2" tubing. Timinq: Doyon #16 will be making a pad to pad move from well DS 14-02A to DS 11-24A on or about January 14 1994. Anchorage , DS 1 1-24A SUMMARY PROCEDURE: Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation (upper most peals are at 10690'). Cut ~;-1/2" tubing @ 8550' MD. Freeze protect. 2. MIRU workover rig. Test intermediate packoff to 5000 psi. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set BPV. ND tree. , NU BOP's. Install tree test plug. Test BOP's to 5000 psi. Pull tree test plug and BPV. 6. Pull and lay down 5-1/2." tubing. Ca. Cb. . . , 10. !!. 12. RIH and install bridge plug @ 9720' md. POOH. Replace intermediate packoff if necessary. RIH with a 9-5/8" section mill and displace well to Xanvis milling fluid - spot I q ppg hi-vis pill from PBTD to base of proposed 9-5/8" section. Cut a @ 45' section · in the 9-5/~" casing starting at +/-82,~,,, MD. POOH RIH with open-ended DP. M',x and pump a minimum of 1 80 sacks of cement to spot balanced kick-off plug from 100' below the base of the section (@ 8440') to 200' above the top of the section (@ 8095'). RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' beiow the top of section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" directional assembly to total depth of 9575' MD/~,~98' TVD or 150' MD below the BOS. Multi-Shot survey w/Sperry-Sun E£S on final trip out of the hole for AOGCC survey requirements. RU Atlas wireline and Icg with the triple combo (GR/CNI/BHC~/Micro SFL/DLL/4- Arm Caliper). In the event that tight hole conditions exist - reduce Ic'gging sonde length and perform 20.H. logging passes. Upon completion of Iogs_;ng make wiper trip prior to running 7" liner. (Note: Use four arm caliper to calculate ;,our cement volumes) Run 7" 29# 13CR80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. XO to 7" 29# L80 liner +/- 300' md above top of Sadlerochit @ RECEIVED BEC 2. 8 0il & Gas Cons. Commission 13. 14. 15. 16. 17. 18, ' 19. 20. 8886'md/8418' tvd. Liner top packer and hanger assembly are to be plain 4140 grade carbon steel, Cement liner calculating cement volume by using information obtained from 4-Arm caliper run while logging. L/D extra 5" DP - that will not be required for clean out run. _Use 20% excess over caliper v¢lume for open hole, Clean out liner to PBTD and test to 3500 psi. Change over to clean inhibited seawater. Test to 3500 psi for 30 minutes. RIH with 4-1/2" 12.6# 13CRL80 NSCT completion string w/Z" packer positioned +/- 200' md above top of Sadlerochit. Sadlerochit top is est/mated @ 8886'md/8418 vd.. ( Reference DS 11-24A completion diagram in Well Plan attachments ). M/U tubing hanger- test SSSV lines to 5000 psi for 10 m/ns. Orient SSSV balance line towards reserve pit. Land tubing hanger and RILDS. Test tubing hanger packoff to 5000 psi. Back out & L/D the landing joint. Set blanking plug. N/D BOPE. N/U tubing head adaptor and 5" tree. Test control lines to 5000 psi. Test 5'.' tree and adaptor to 5000 psi. Pull the test plug with a lubricator. Pressure up on the 4-1/2" 12.6# 13C.;R80 tubing to 4000 psi to set the production packer. Maintain tubing pressure at 4000 psi for 30 minutes after setting packer and record as the tubing test. Bleed off 4-1/2" tubing pressure to +/- 1500 psi. Pressure test tubing x 9-5/8" annulus to 3500 psi for 30 minutes. Record the test on a Barton chart. Bleed off the annular pressure prior to bleeding off the tubing pressure. Bleed off the tubing pressure. Pressure up to 2900 psi on the annulus to shear out the RP valve in the top GLM position. Displace the tubing w/enough diesel to freeze protect the annulus to 2200' tvd. Allow the diesel to U-tube to the tubing. If possible have the well freeze protected by gas by the PE's in the WOA or Drill Site Maintenance in the EOA. A potential gas source nearby will be required - high GOR well or artificial gas lift line. RECEIVED E) E C 2 8 'l 9"~ /,,,.-~,.~,- ~,,-,~. 0il & Oas 0ans. 6o~nrnissien Anchorage lU 8600 8700 ....... 8800 8900 PRUDHOE BAY DF~I_LING GROUP Marker !Qenlification A) TIE-IN / KOP D) ENO OF 6/]00 CURVE C) TARGET O] TD 9000- J 9]00- 9200 ~O 8~00 8689 8KB SECTN [NCLN 7902 ~1~5 · 20.J5 8253 ]349 32.7G 9425 8872 1747 32.76 95?5 8998 J828 32.76 . 700 BO< ..... 900 1000 % % DS 11-24A (P2) VERTICAL SECTION VIEW Section aL' 3~5.1a TvD Scale.' 1 1ncr, -- 200 feet Oep Sca]e.' 1 inch : 200 feel Drawn ' 12/!3/93 , ,, , /nadr i 1 ] Sch ) umbergen I O,--',,-, C_L, Sect ion Departure !700 lBCO 1900 2000 · . I]:L.--i.]-- 1~'~`3 1.3, ,N1 I-F, UI'I I.]F, EH I - LHI'IU/HI~IHIJIX ILL I U FDU F_I~U II~EF--A3 F . ~D PRUDHOE BAY DRILLING GROUP , - ......... ,,,l DS '11-24A (P2) PLAN Vl-EN CLOSURE ..... : 2323 feet at Azimuth 277.05 DECLINA}t0N.: 30.083 E SCALE ....... : ~ inch = ~00 Feet DRAWN ....... : ~2/~3/§3 Anadr i ]1 Schlumber9en _ Narker I~entJ~icat~on MD N/S E/W A) TIE-iN / KOP 8300 ~29 ~S24 B) END OF 6/100 CURVE $g~9 55 1~67 C) TARGET 9425 227 2246 D) TO 9575 285 2305 i j TARGET 250 F: RADIUS I : 1 . R E(.EIV,ED j : DEC ~ .I '~~! .......... ii '' Ii/ /"~ <al Oii-&"~ asa ~chorageC°ns' ]ommi~i too~ .............. . .. <- WE~T , ['. TOTA~ P. 86 STATE OF ALASKA ALA...,A OIL AND GAS CONSERVATION COMMISSI_., APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing ~ Repair well~ Plugging x Time extension ~ Stimulate __ Change approved program ~ Pull tubing Vadance ~ Perforate __ Other x __ Plugback Ior redrlll 2. Name of Operator 5. Type of Well: 6. ARCO Alaska,/nc. Development x Exploratory __ 3. Address Stratigraphic__ 7, P. O. Box 196612, Anchorage, Alaska 99519-6612 service__ 4. Location of well at surface 8. 217'NSL, 180' WEL, SEC. 28, T11N, R15E At top of productive interval 119' NSL, 2215' WEL, SEC. 28, T11N, R15E At effective depth 212' NSL,. 2477' WEL, SEC. 28, T11N, R15E At total depth 223' NSL, 2501' WEL, SEC. 28, T11N,' R15E Datum elevation (DF or KB) KBE = 58' feet Unit or Property name Prudhoe Bay Unit Well number 11-24 9. Permit number 86-129 10. APl number 50- 029-21623 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9535 feet Plugs (measured) 9021 feet 9474 feet Junk (measured) 8966 feet Casing Length Size Cemented Structural Conductor 98' 20" 1900 # Poleset Surface 2447' 13-3/8" 2000 sx CS III & Intermediate 975 sx CS II Production 9459' 9-5/8" 823 sx "G"/300 sx CS I Liner Perforation depth: measured 9336'-9366' Measured depth True vertical depth 98' 98' 25O5' 25O5' 9517' RECEIVED 9005' true vertical 8842'-8868' DEC 2 8 1993 Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 8715'MD ^l~ska 0il & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker SB-3 packer @ 8592' MD; 5-1/2", A VA SSS V @ 2181' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. E~timated date for commencing operation 12/2 7/93 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 15. Status of well classification as: Gas Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Suspended Date Conditions of approval: Nc,".,, Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- I Approval No. ?, 3 - '~ ~- ? Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** A P~ROVE DATE / /...,,, ..... . /LF.'.L/~.>?/!~ ~ "[~2 thru '8"1 (4) Casg (5) BOPE [gr./~l~thru 13]/:~ [10 & 13] [14 thru 22 [23 thru Lease & Well ~ A:~::'...'-~.._ :: ::'2...,_'~" :" .'" ,~:"'", NO REMARKS Company. YES Is permit fee attached ............ eee.eeeeeeeeeeeeeeeeee~eeeee.e..ee. le 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undndicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... . 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nLrnber appropriate .......................................... 13. Does well have a unique name & nLrnber ................................ 14 Is conductor string provided ......... -~/-~- 15. Wi l to 16. Is 17. Wi 1 18. Wi 1 19. Wi l 20. Is 21 Is 22. Is 23. Is 24. Is drilling fluid program schematic & list of equi 25. Are necessary diagrams & descriptions of diverter 26. Does BOPE have sufficient pressure rating -- test 27. 28. 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. tr enough cement used to circulate on conductor & surface ............ ~,' 1 cement tie in surface & intermediate or production strings ...... a 1 cement cover all known productive horizons ..................... ~ .. 1 all casing give adequate safety in collapse, tension, and burst. ~-]W~' well to be kicked off from an existing wellbore ...... ~ , ooeOu e o. ...... adequate wellbore separation proposed ............................. ~ a diverter system required ........................................ S~ pment adequate ..... & BOPE attached .... to ~-~dNP psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other [29 thru 31] (7) Contact [32] (8) Addl FOR EXPLORATORY & STRATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone nLrnber of contact to supply weekly progress data ...... 33. Additional requirements ............................................. // geology' engineering: . rev 6~93 jo/6.011 INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ..- " ~ /' :3 17 ~_ ! 0 ~ ~ . Additional remarks' Exp~ Inj RedFFT1X Rev UM >( MERIDIAN: SM WELL TYPE' 0 --I ~0 m z Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 11-24A FIELD NAME : PRUDHOE BAY BOROUGH ' NORTH SLOPE STATE : ALASKA API NUMBER : 500292162301 REFERENCE NO : 98584 NOV ?~0 1998 ^ncl~orag~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/12 ORIGIN : FLIC REEL NA~E : 98584 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-24A, API# 50-029-21623-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/12 ORIGIN · FLIC TAPE NAME : 98584 CONTINUATION # .. 1 PREVIOUS TAPE : CO~4~J~T : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-24A, API# 50-029-21623-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 11-24A API NUMBER: 5002921623 O1 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLU~iBERGER WELL SERVICES TAPE CREATION DATE: 12-NOV-98 JOB NUMBER: 98584 LOGGING ENGINEER: VETROMILE OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 28 TOWNSHIP: 1 iN RANGE: 15E FNL: FSL : 217 FEL: 180 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 54.50 DERRICK FLOOR: 53.50 GROUND LEVEL: 28. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 8. 000 7. 000 9614.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DLL LDWG CURVE CODE: GR RUN NUMBER: PASS ~ER : DATE LOGGED: 1994 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH 88888.0 9383.0 9381.5 9380.5 9378 0 9375 0 9374 5 9373 0 9370 5 9369 5 93 68 0 93 67 5 93 61 5 93 60 0 9355 0 9351 0 9329 5 9327 0 9325 5 9323 0 9320 0 9311 0 9310 0 9303 0 9297.0 9292 0 9289 0 9282 5 9275 0 9270 5 9268 0 9257.0 9254.5 9251.5 9239.0 9237.0 9224.0 9220. 0 9215.0 9208.0 9207.5 9205.0 9200.5 9195.5 9195.0 .......... EQUIVALENT UNSHIFTEDDEPTH GRCH CNTG .............. 88888.5 9382.0 9378.5 9375.0 9373.5 9370.5 9368.0 9362.5 9356.0 9352.5 9330 5 9327 5 9325 5 9324 0 9320 5 9312 0 9304.0 9292.5 9289.0 9283.5 9275.0 9271.5 9268.5 9257.5 9256.0 9252.0 9240.0 9237.5 9224.5 9220.5 9214.5 9208.5 9205.5 9200.5 9196.0 88889.5 9384.5 9382.0 9379.0 9373.5 9370.5 9368.0 9360.0 9312.0 9298.0 9240.0 9208.5 9196.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 9190 0 9179 5 9177 5 9165 0 9155 5 9138 0 9124 5 9119 5 9117 0 9106.5 9103.0 9100.5 9097.5 9090.0 9089.5 9084.0 9075.5 9071.0 9069.5 9066.0 9062.0 9059.0 9056.5 9051.5 9050.0 100.0 $ 9190.5 9181.0 9178.5 9166.0 9158.0 9140.0 9121.5 9108.0 9104.0 9097.0 9090.5 9085.0 9076.0 9072.0 9070.5 9063.5 9060.0 9058.0 9052.5 9051.0 101.0 9166.0 9126.0 9117.0 9104.0 9101.0 9090.0 9072.5 9067.5 9063.5 101.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 11-24A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE DLL GAMY~A RAY, ALSO PASS #1 NPHI AND THE DLL GANk~A RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ PAGE **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCPO~: 0.5000 FILE SU~94ARY LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9387.5 9047.0 CNTG 9392.5 9047.5 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NOWB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 GR DLL GAPI 1224650 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9532.500 NPHI.CNTG -999.250 ENPH. CNTG NNAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG GR.DLL 122.870 DEPT. 8276.500 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG GR.DLL 102.310 -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL. CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION . O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREmENT: 0.5000 FILE SUlZ~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9388.0 9024.5 CNTG 9393.0 9026.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9382.5 9380.0 9377.5 9375.5 9374.5 9372.0 9369.5 9367.0 9361.0 9357.5 9354.5 9346.0 9342.5 9335.0 9331.0 9326.0 9324.0 9323.0 9322.5 9319.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTG .............. 88889.0 88890.0 9378.5 9375.0 9373.5 9370.5 9368.0 9356.0 9346.0 9332.5 9325.5 9323.5 9320.5 9384.5 9382.0 9379.0 9376.0 9370.5 9361.5 9358.0 9346.0 9337.0 9327.5 9325.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 9311.0 9310.5 9307.0 9303 0 9302 5 93 O1 5 9297 5 9296 0 9291 0 9285 5 9284.0 9283.5 9274.0 9270.0 9264.5 9261.5 9259.0 9256.5 9256.0 9254.5 9251.0 9248.0 9244.5 9243.5 9238.5 9238.0 9236.0 9235.0 9232.5 9230.0 9227.0 9222 5 9218 5 9215 0 9212 0 9208 5 9204 5 9202 5 9195 5 9195.0 9193.0 9185.5 9181.5 9179.5 9179.0 9176.5 9166.5 9165.0 9154.5 9151.0 9144.0 9143.0 9133.0 9131.0 9121.0 9312.0 9309.0 9305.0 9302.0 9299.0 9285.5 9271.5 9265.5 9260.0 9257.5 9256.0 9252.0 9245.5 9244.0 9240.0 9237.5 9230.5 9224.0 9220.5 9215.0 9209.5 9205.5 9196.0 9194.5 9184.0 9181.0 9168.5 9156.5 9144.5 9!33.0 9314.0 9305.5 9298.0 9292.0 9288.0 9284.5 9275.5 9263.0 9258. 0 9250. 0 9240. 0 9237.5 9233.5 9228. 0 9218. 0 9213.0 9204. 0 9196. 0 9188. 0 9180.5 9178.5 9166. 0 9152.5 9145.5 9133.5 9120.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 9118.0 9121.0 9110.5 9112.5 9109.0 9110.5 9104.0 9105.5 9102.5 9103.5 9102.0 9104.0 9099.5 9101.0 9098.0 9099.0 9093.0 9093.5 9083.0 9085.0 9084.5 9070.5 9072.0 9070.0 9072.5 9068.5 9070.5 9066.0 9068.0 9061.5 9063.5 9063.5 9058.5 9060.0 9061.0 9054.0 9054.0 9052.0 9052.5 100.0 100.5 102.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: ** SET TYPE - CHAN ** NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1224650 O0 000 O0 0 2 1 1 4 68 0000000000 * * DA TA * * DEPT. 9393.000 NPHI.CNTG 26.721 ENPH. CNTG 27.423 CPHI.CNTG NRAT. CNTG 2.631 CRAT. CNTG 2.868 ENRA.CNTG 4.390 NCNT. CNTG FCNT. CNTG 582.994 CNTC. CNTG 1823.375 CFTC. CNTG 624.549 CNEC. CNTG CFEC. CNTG 592.053 GRCH. CNTG -999.250 TENS.CNTG 3011.000 CCL.CNTG DEPT. 9024.500 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 EArRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 19.335 TENS. CNTG -999.250 CCL.CNTG 29.057 2119.379 2599.206 0.043 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 10 **** PILE HEADER **** FILE NA~4E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUR~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9388.0 9045.5 CNTG 9393.0 9045.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NTJMBER: 1 BASELINE DEPTH 88888.0 9387.5 9385.5 9383.0 9380.5 9380.0 9378.0 9377.5 9376.0 9374.0 9372.0 9369.5 9367.5 9362.0 9361.0 9358.0 9354.5 9349.5 9342.0 9339.5 9337.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88889.0 88890.0 9389.5 9386.5 9384.5 9381.5 9382.0 9378.5 9379.0 9376.5 9375.0 9372.0 9370.5 9368.0 9367.5 9362.5 9361.5 9358.0 9356.0 9352.5 9345.5 9345.5 9343.5 9340.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 11 9334.5 9331.5 9329.0 9323.0 9320.0 9317.0 9311.5 9311.0 9307.0 9303.5 9303.0 9302.0 9297.5 9297.0 9292.0 9291.5 9283.5 9277.5 9276.5 9274.5 9273.5 92 69.5 92 67.5 9265.0 9262.5 92 62.0 92 61.0 9259.0 9256.5 9253 5 9251 0 9245 5 9242 5 9238 5 9236 0 9234.5 9231.5 9231.0 9229.0 9227.0 9223.0 9216.0 9213.5 9209.5 9209.0 9206.0 9203.5 9195.5 9195.0 9193.0 9189.5 9188.5 9183.5 9180.0 9179.5 9330.5 9323.5 9320.5 9316.5 9312.5 9309.0 9304.5 9302.5 9298.5 9293.0 9285.0 9276.5 9275.0 9271.5 9268.5 9265.5 9263.5 92 61.5 9259.5 9252.0 9245.5 9244.0 9240.0 9235.5 9231.5 9229.0 9224.0 9214.0 9209.0 9205.0 9196.0 9190.0 9183.5 9181.0 9337.0 9333.0 9314.0 9305.5 9298.0 9292.0 9279.0 9275.0 9263.0 9258.0 9255.5 9243.5 9237.0 9233.5 9230.0 9223.5 9217.5 9210.5 9207.5 9196.0 9194.5 9188.0 9180.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 12 9173.0 9174.0 9166.5 9168.5 9165.0 9166.0 9166.0 9159.0 9160.0 9158.5 9159.5 9150.5 9152.5 9143.0 9145.5 9137.0 9140.0 9136.0 9136.5 9130.0 9132.0 9119.5 9121.0 9118.0 9119.5 9104.5 9105.5 9102.5 9103.5 9104.0 9100.0 9101.0 9098.5 9099.0 9095.0 9094.5 9093.5 9093.5 9091.5 9092.5 9083.5 9084.5 9074.5 9076.0 9070.5 9072.0 9072.5 9069.0 9070.5 9066.0 9067.0 9065.5 9067.5 9062.5 9063.5 9061.5 9063.5 9059.0 9061.0 9058.5 9060.0 9050.0 9051.0 100.0 101.5 101.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 13 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 ArRAT CNTG 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1224650 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9393.000 NPHI.CNTG 19.203 ENPH. CNTG 25.032 CPHI.CNTG NR~T. CNTG 2.422 CRAT. CNTG 2.431 ENRA. CNTG 4.129 NCNT. CNTG FCNT. CNTG 598.536 CNTC. CNTG 1694.727 CFTC. CNTG 619.358 CNEC. CNTG CFEC. CNTG 601.397 GRCH. CNTG -999.250 TENS. CNTG 3081.000 CCL.CNTG DEPT. 9045.000 NPHI.CNTG 10.559 ENPH. CNTG 14.584 CPHI.CNTG NRAT. CNTG 1.890 CRAT. CNTG 1.799 ENRA.CNTG 2.873 NCNT. CNTG FCNT. CNTG 1606.673 CNTC. CNTG 2987.766 CFTC. CNTG 1666.819 CNEC. CNTG CFEC. CNTG 1213.856 GRCH. CNTG -999.250 TENS.CNTG 3029.000 CCL.CNTG 26.294 2016.806 2483.361 0.042 12.947 3018.748 3487.111 0.088 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 14 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~iE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS AU3MBERS 1, 2, 3, CNTG $ REFLARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 15 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 IFRAT CNAV 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1224650 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9392.500 NPHI.CNAV 28.922 NRAT. CNAV 3.047 CPHI.CNAV CRAT. CNAV 2.989 ENPH. CNAV 30.292 ENRA.CNAV 4.690 NCNT. CNAV FCNT. CNAV 574.284 CNTC. CNAV 1816.200 CFTC. CNAV 626.669 CNEC. CNAV CFEC. CNAV 552.347 GRCH. CNTG -999.250 28.759 1741.833 2589.788 DEPT. 9047.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA. CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 11.972 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC V~RSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NANiE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRENiENT: 0.5000 FILE SUMMARY VEN-DOR TOOL CODE START DEPTH CNTG 9415.5 $ LOG HEADER DATA STOP DEPTH 9043.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (?T) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 15-0CT-98 8Cl -205 1804 15-0CT-98 9406.0 9404.0 9024.0 9391.0 1800.0 TOOL NUMBER ........... SGC- SA CNT-G 8.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 17 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9614.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLH~ (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) .. EPI THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): RE~AP~KS: LOG TIED INTO ATLAS CNL DATED 17-FEB-1993 PUMPED 290 BBLS CRUDE TO KNOCK DOWN WELL @ 5-8 BBL/MIN PUMPED 175 BBLS CRUDE DURING LOGGING @ 2 BBL/MIN PUMPED 10 BBLS DIESEL TO FREEZE PROTECT LOGGED THREE PASSES AT 30 FPM TAGGED PBTD AT 9404' THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 18 TYPE REPR CODE VALUE .............................. 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APIAPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELE~ CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1224650 NPHI PS1 PU 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PSl CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 RCENPS1 CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1224650 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9415.500 NPHI.PS1 32.309 ENPH. PS1 23.246 TNPH. PS1 TNRA.PS1 3.175 RTNR.PS1 3.250 ENRA.PS1 3.928 CFEC. PS1 CNEC. PS1 2350.899 RCEF. PS1 606.171 RCEN. PS1 2222.195 RCNT. PS1 RCFT. PS1 484.185 CNTC. PS1 1560.567 CFTC. PSi 503.328 NPOR.PS1 GR.PS1 33.047 TENS.PSi 2502.000 CCL.PS1 0.057 31.841 598.466 1593.313 31.841 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 19 DEPT. 9043.000 NPHI.PS1 TArRA.PS1 1.784 RTArR.PS1 ClVEC. PS1 3448.015 RCEF. PS1 RCFT. PS1 1665.673 CNTC. PS1 GR.PS1 18.501 TENS.PSi 10.371 ENPH. PS1 1.792 E1VRA.PS1 1140.884 RCEN. PS1 3020.118 CFTC.PSI 3032.000 CCL.PS1 14.609 TNPH. PS1 2.876 CFEC. PS1 3136.197 RCNT. PS1 1762.563 NPOR.PS1 -999.250 12.313 1172.911 2989.052 12.531 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION . O01CO1 DATE · 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE H~ER FILE~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCR2~TT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 9422.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9012.5 15-0CT-98 8Cl -205 1804 15-0CT-98 9406.0 9404.0 9024.0 9391.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 20 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NEUTRON $ TOOL NUMBER ........... SGC-SA CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.000 9614.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) '. FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO ATLAS CNL DATED 17-FEB-1993 PUMPED 290 BBLS CRUDE TO KNOCK DOWN WELL @ 5-8 BBL/MIN PUMPED 175 BBLS CRUDE DURING LOGGING @ 2 BBL/MIN PUMPED 10 BBLS DIESEL TO FREEZE PROTECT LOGGED THREE PASSES AT 30 FPM TAGGED PBTD AT 9404 ' THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1224650 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 22 DEPT. 9422.500 NPHI.PS2 TNRA.PS2 2.931 RTNR.PS2 CNEC.PS2 2217.063 RCEF. PS2 RCFT. PS2 484.185 CNTC. PS2 GR.PS2 27.539 TENS.PS2 DEPT. 9012.500 NPHI.PS2 TNRA.PS2 1.903 RTNR.PS2 CNEC. PS2 3480.583 RCEF. PS2 RCFT. PS2 1420.144 CNTC. PS2 GR.PS2 23.246 TENS.PS2 27.857 ENPH. PS2 3.000 ENRA.PS2 484.185 RCEN. PS2 1438.443 CFTC. PS2 2318.000 CCL.PS2 11. 851 ENPH. PS2 1. 929 ENRA. PS2 1162.180 RCEN. PS2 2771. 632 CFTC. PS2 2935. 000 CCL. PS2 29.777 4.638 2095.687 503.328 0.123 15.477 2.988 3220.079 1464.776 -999.250 TNPH. PS2 CFEC. PS2 RCNT. PS2 NPOR.PS2 TNPH. PS2 CFEC. PS2 RCNT. PS2 NPOR.PS2 28.121 478.031 1468.626 28.121 14.843 1175.377 3047.682 15.925 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE ' FLIC VERSION . O01CO1 DATE . 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~mIARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 9420.0 9042.5 $ LOG HEADER DATA DATE LOGGED: 15-0CT-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 23 SOFTWARE VERSION: TI~fE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (?T) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8Cl-205 1804 15-0CT-98 9406.0 9404.0 9024.0 9391.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAP~qA RAY CNTG COMPENSATED NEUTRON $ TOOL NUMBER SGC-SA CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.000 9614.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) '. SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) '. 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 15000 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO ATLAS CNL DATED 17-FEB-1993 PUMPED 290 BBLS CRUDE TO KNOCK DOWN WELL @ 5-8 BBL/MIN PUMPED 175 BBLS CRUDE DURING LOGGING @ 2 BBL/MIN PUMPED 10 BBLS DIESEL TO FREEZE PROTECT LOGGED THREE PASSES AT 30 FPM LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 24 TAGGED PBTD AT 9404' THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 TN~A PS3 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 RTI~R PS3 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 E1VRA PS3 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 RCEN PS3 CPS 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1224650 O0 000 O0 0 7 1 i 4 68 0000000000 NPOR PS3 PU 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS$ GAPI 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ND?4~ SAMP ELE~ CODE (HEX) TENS PS3 LB 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1224650 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9420.000 NPHI.PS3 51.602 ENPH. PS3 38.475 TNPH. PS3 TNRA.PS3 4.233 RTNR.PS3 4.333 ENRA.PS3 5.481 CFEC. PS3 CNEC. PS3 2640.173 RCEF. PS3 487.876 RCEN. PS3 2495.632 RCNT.PS3 RCFT. PS3 365.337 CNTC. PS3 1572.614 CFTC.PS3 379.781 NPOR.PS3 GR.PS3 33.298 TENS.PS3 2277.000 CCL.PS3 0.048 DEPT. 9042.500 NPHI.PS3 10.215 ENPH. PS3 14.670 TNPH. PS3 TNRA.PS3 1.771 RTNR.PS3 1.815 ENRA.PS3 2.884 CFEC.PS3 CNEC. PS3 3445.764 RCEF. PS3 1155.106 RCEN. PS3 3128.427 RCNT. PS3 RCFT. PS3 1795.865 CNTC. PS3 3009.329 CFTC.PS3 1782.148 NPOR.PS3 GR.PS3 20.052 TENS. PS3 3039.000 CCL.PS3 -999.250 48.944 481.675 1605.612 48.944 11.566 1194.802 3151.039 11.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/12 ORIGIN . FLIC TAPE NAME : 98584 CONTINUATION # : 1 PREVIOUS TAPE : COf~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-24A, API# 50-029-21623-01 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-NOV-1998 09:54 PAGE: 2 6 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 98/11/12 ORIGIN : FLIC REEL NAME : 98584 CONTINUATION # : PREVIOUS REEL : COf~4~f : ARCO ALASKA INC., PRUDHOE BAY, D.S. 11-24A, API# 50-029-21623-01 966l 9 0 d~8 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/21 ORIGIN : FLIC REEL NAME : 96212 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-24A, API #50-029-21623-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/21 ORIGIN . FLIC TAPE NAME : 96212 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-24A, API #50-029-21623-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 11-24A API NUMBER: 5002921623 O1 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 21-AUG-96 JOB NUMBER.. 96212 LOGGING ENGINEER: D. LUCAS OPERATOR WITNESS: J. JULIAN SURFACE LOCATION SECTION: 28 TOWNSHIP: 1 IN RANGE: 15E FNL: FSL: 217 FEL: 180 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 54.50 DERRICK FLOOR: 53.50 GROUND LEVEL: 28. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT)WEIGHT (LB/FT) 1ST STRING 9. 625 8283 . 0 47. O0 2ND STRING 7. 000 9614.0 29. O0 3RD STRING 4. 500 8718.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DLL LDWG CURVE CODE: GR RUN NUMBER: 1 PASS ~ER : 1 DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 9406.5 9401.0 9388.5 9387.0 9384.0 9379.5 9373.5 9366.0 9365.5 9360.0 9353.5 9328.5 9323.5 9319.0 9318.5 9309.5 9307.0 9291.0 9270.0 9260.5 9257.5 9254.0 9238.0 9234.0 9223.5 9223.0 9213.0 9209.0 9207.5 9203.0 9196.0 9195.0 9179.5 9178 5 9174 0 9170 0 9165 0 9134 5 9116 0 9102 5 9099.5 9089.5 9089.0 9083.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD .............. 88889.0 88893.0 9388.0 9375.0 9368.0 9362.0 9356.5 9330.5 9325.5 9321.0 9312.0 9309.5 9292.5 9271.0 9259.0 9255.5 9240.0 9235.5 9224.5 9214.0 9208.5 9205.0 9197.5 9181.0 9171.5 9166.5 9135.5 9118.0 9101.0 9089.0 9411.5 9405.0 9393.0 9388.0 9382.5 9367.5 9326.0 9320.5 9261.5 9240.0 9224.5 9208.5 9196.5 9178.5 9175.0 9166.5 9103.5 9101.0 9090.0 9085.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 9074.0 9076.0 9066.0 9068.0 9062.0 9063.5 9061.5 9063.5 9056.5 9057.5 100.0 102.0 101.0 $ REMARKS: THE DATA CONTAINED HEREIN IS THE CASED HOLE 3 PASS CNTD LOGGED ON ARCO ALASKA'S D.S. 11-24A WELL. THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT CASED HOLE PASS #1 GAMMA RAY TO OPEN HOLE GA~ff4A RAY AND PASS #1 NPHI TO OPEN HOLE GA~94A RAY CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUR~r~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9389.0 9047.0 CNTD 9412.0 9047.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. .......... EQUIVALENT UNSHIFTED DEPTH GRCH CNTD .............. REMARKS: THIS FILE CONTAINS CNTD PASS #1. SHIFTS WERE APPLIED TO THIS DATA. NO PASS TO PASS LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 4 LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 11-24A Well Name APIN 500292162301 API Serial Number FL 0217' FSL & 0180' FEL Field Location SECT 28 Section TOWN liN Township RANG 15E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN J. JULIAN Witness Name SON 100465 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 54.5 Above Permanent Datum EKB FT 54.5 Elevation of Kelly Bushing EDF FT 53.5 Elevation of Derrick Floor EGL FT 28. Elevation of Ground Level TDD FT 9574. Total Depth - Driller TDL FT 9410. Total Depth - Logger BLI FT 9408. Bottom Log Interval TLI FT 9050. Top Log Interval DFT SEA WATER Drilling Fluid Type TLAB 11:00 23-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. ~T Raw Thermal Neutron Ratio CRAT Thermal Neutron Ratio Calibrated NCNT RAW NEAR CNT COUNTS FCNT RAW FAR CNTCOUNTS CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray in Casing TENS Surface Tension CCL CCLAmplitude GR API-Corrected Gamma Ray LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100465 O0 000 O0 0 1 1 1 4 68 NPHI CNTD PU-S 100465 O0 000 O0 0 1 1 1 4 68 NRAT CNTD 100465 O0 000 O0 0 1 1 1 4 68 CRAT CNTD 100465 O0 000 O0 0 1 1 1 4 68 NCNT CNTD CPS 100465 O0 000 O0 0 1 1 1 4 68 FCNT CNTD CPS 100465 O0 000 O0 0 1 1 1 4 68 CFTC CNTD CPS 100465 O0 000 O0 0 1 1 1 4 68 CNTC CNTD CPS 100465 O0 000 O0 0 1 1 1 4 68 GRCH CNTD GAPI 100465 O0 000 O0 0 1 1 1 4 68 TENS CNTD LB 100465 O0 000 O0 0 1 1 1 4 68 CCL CNTD V 100465 O0 000 O0 0 1 1 1 4 68 GR DLL GAPI 100465 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9532.500 NPHI.CNTD -999.250 ATRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD -999.250 CCL.CNTD -999.250 GR.DLL -999.250 -999.250 122.870 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: DEPT. 8276.500 NPHI. CNTD -999.250 NRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD GRCH. CNTD -999. 250 TENS. CNTD -999. 250 CCL. CNTD -999. 250 CRAT. CNTD -999. 250 CNTC . CNTD -999. 250 GR. DLL -999.250 -999.250 102.310 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE . FLIC VERSION : O01CO1 DATE : 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9389.0 9047.0 CNTD 9412.0 9047.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88889.5 88890.5 9402.5 9405.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 9380.5 9374.0 9370.5 9368.0 9366.5 9366.0 9362 5 9359 0 9357 5 9354 0 9337 5 9329 5 9321 5 9319 5 9318 0 9310 5 93 O1 0 9296 5 9284 0 9277 5 9264 5 9255.0 9254.0 9251. 0 9239.0 9238.5 9233.0 9230.0 9229.5 9227.0 9223.5 9210.5 9209.5 9205.0 9203.5 9201.5 9198.0 9194.0 9180.0 9177.5 9170.0 9166.5 9165.0 9157.5 9135.0 9132.0 9131.0 9125.0 9117.0 9102.5 9094.5 9091.0 9084.0 9075.0 9071.0 9375.5 9372.5 9370.5 93 68. 0 93 60.5 9356.5 9331.0 9323.5 9321.0 9312.5 9302.5 9285.0 92 65.5 9256.0 9240.5 9234.0 9231.0 9225.0 9209.0 9204.5 9181.5 9171.0 9166.0 9133. 0 9118.5 9097.0 9084.5 9075.0 9382.5 9368.0 9363.5 9359.0 9339.0 9319.0 9297.5 9285.0 9278.0 9265.0 9255.0 9252.5 9240.0 9230.0 9227.5 9211.0 9205.5 9202.5 9199.0 9194.5 9177.0 9167.5 9158.5 9136.0 9131.5 9126.0 9103.5 9091.5 9085.5 9072.5 LIS Tape V~rification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 9062.5 9062.0 9063.5 9058.0 9053.5 9051 . 5 9053 . 5 100.0 102.0 $ 9063.5 9059.0 9054.0 100.5 REMARKS: THIS FILE CONTAINS CNDT PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT GRCH PASS #2 TO GRCH PASS #1 AND NPHI PASS #2 TO NPHI PASS #1 CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 11-24A Well Name APIN 500292162301 API Serial Number FL 0217' FSL & 0180' FEL Field Location SECT 28 Section TOWN 11N Town ship RANG 1SE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 100465 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 54.5 Above Permanent Datum EKB FT 54.5 Elevation of Kelly Bushing EDF FT 53.5 Elevation of Derrick Floor EGL FT 28. Elevation of Ground Level TDD FT 9574. Total Depth - Driller TDL FT 9410. Total Depth - Logger BLI FT 9408. Bottom Log Interval TLI FT 9050. Top Log Interval DFT SEA WATER Drilling Fluid Type TLAB 11:00 23-JUL-96 Time Logger at Bottom LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: TABLE TYPE : CURV DEFI DEPT Dep th NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. NRAT Raw Thermal Neutron Ratio CRAT Thermal Neutron Ratio Calibrated NCNT RAW NEAR CNT COUNTS FCNT RAW FAR CNT COUNTS CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT ?T 100465 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 100465 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 100465 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 100465 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 100465 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 100465 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 10 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CFTC CNTD CPS 100465 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 100465 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 100465 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 100465 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 100465 O0 000 O0 0 2 1 1 4 68 0000000000 * * DA TA * * DEPT. 9414. 500 NPHI. CNTD 26. 485 NRAT. CNTD 4 . 316 CRAT. CNTD NCNT. CNTD 3382. 509 FCNT. CNTD 769. 133 CFTC. CNTD 723. 598 CNTC. CNTD GRCH. CNTD -999. 250 TENS. CNTD 1365. 000 CCL. CNTD O. 000 DEPT. 9047.500 NPHI.CNTD 13.129 NRAT. CNTD 2.774 CRAT. CNTD NCNT. CNTD 7951.120 FCNT. CNTD 2978.979 CFTC. CNTD 2866.217 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1435.000 CCL. CNTD 0.000 4.608 3329.606 2,822 7916.441 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' O01CO1 DATE · 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 11 FILE SU~gVARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9389.0 9008.0 CNTD 9412.0 9008.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888 0 9388 5 9381 5 9379 5 9374 0 9373 5 9366.5 9365.5 9361.5 9358.0 9353.5 9338.5 9328.5 9323.5 9310.0 9309.5 9300.5 9297.0 9296.0 9291.0 9283.5 9282.0 9273.0 9263.5 9254.5 9251.0 9243.0 9238.0 9237.5 9234.5 9231.5 9227.0 9223.0 9222.5 9213.5 9212.5 9209.5 9204.5 9195.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88889.5 88893.0 9375.0 9368.0 9356.5 9330.5 9312.5 9303.0 9299.0 9292.5 9284.5 9274.5 9265.0 9256.0 9240.5 9236.5 9229.0 9224.5 9213.0 9205.5 9393.5 9385.5 9382.5 9376.5 9368.0 9363.5 9360.0 9341.0 9326.0 9312.0 9297.5 9284.0 9274.5 9265.0 9256.0 9253.0 9245.0 9240.0 9234.0 9224.5 9215.5 9211.0 9205.5 9196.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 12 9193. 9192. 9179. 9179. 9175. 9166. 9165. 9164. 9136. 9131. 9130. 9127. 9116. 9105 9102 9099 9090 9084 9083 9078 9071 9070 9062 9061 9050 100.0 $ 9195.5 9181.0 9166.5 9137.0 9133.0 9127.5 9118.5 9107.0 9085.0 9072.5 9063.5 102.0 9194.0 9178.5 9175.0 9167.5 9166.5 9131.5 9103.5 91 O1.0 9091.5 9085.5 9081.5 9072.5 9063.5 9051.5 101.5 REMARKS: THIS FILE CONTAINS CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT GRCH PASS #3 TO GRCH PASS #1 AND NPHI PASS #3 TO NPHI PASS #1 CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NA TI WITN SON PDA T ARCO ALASKA INC. PRUDHOE BAY DS 11-24A 5002921623 O1 0217' FSL & 0180' FEL 28 liN 1SE NORTH SLOPE ALASKA USA J. JULIAN 100465 MSL Company Name Field Name Well Name API Serial Number Field Location Section Township Range Court ty State or Province Nation Wi tness Name Service Order Number Permanent datum LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 13 T UNI VAL U DEFI EPD FT O . LMF RKB APD FT 54.5 EKB FT 54.5 EDF FT 53.5 EGL FT 28. TDD FT 9574. TDL FT 941 O. BLI FT 9408. TLI FT 9050. DFT SE~ WATER T~ 11:00 23-JUL-96 Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom TABLE TYPE : CURV DEFI ........................................................... DEPT Dep th NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. NRAT Raw Thermal Neutron Ratio CRAT Thermal Neutron Ratio Calibrated NCNT RAW NEAR CNT COUNTS FCNT RAW FAR CNT COUNTS CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Ampli rude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 14 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100465 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 100465 O0 000 O0 0 3 1 1 4 68 0000000000 AFRAT CNTD 100465 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 100465 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 100465 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 100465 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 100465 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 100465 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 100465 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 100465 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 100465 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9417. 000 NPHI. CNTD 31 . 035 NRAT. CNTD 4. 920 CRAT. CNTD NCNT. CNTD 3496. 063 FCNT. CNTD 686. 695 CFTC. CNTD 658.171 CNTC. CNTD GRCH. CNTD -999. 250 TENS. CNTD 131 O. 000 CCL. CNTD O. 000 DEPT. 9009.500 NPHI.CNTD 15.088 NRAT. CNTD 2.893 CRAT. CNTD NCNT. CNTD 7306.830 FCNT. CNTD 2443.992 CFTC. CNTD 2303.757 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1440.000 CCL.CNTD 0.000 5.169 3397.585 3.089 7200.660 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 15 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREbIENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3 CNTD REMARKS: THE ARITH~ETIC AVERAGE OF PASSES 1,2, & 3 WAS COMPUTED AFTER ALL DEPTH SHIFTS AND CLIPPING WAS APPLIED. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDA T EPD FT LMF APD FT EKB FT EDF FT EGL FT TDD FT ARCO ALASKA INC. PRUDHOE BAY DS 11-24A 5002921623 O1 0217' FSL & 0180' FEL 28 liN 1SE NORTH SLOPE ALASKA USA J. JULIAN 100465 MSL O. 54.5 54.5 53.5 28. 9574. Company Name Field Name Wel 1 Name API Serial Number Field Location Section Township Range Court ty State or Province Nation Wi tness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 16 TUNI VALU DEFI TDL FT 9410. Total Depth - Logger BLI FT 9408. Bottom Log Interval TLI FT 9050. Top Log Interval DFT SEA WATER Drilling Fluid Type TLAB 11:00 23-JUL-96 Time Logger at Bottom TABLE TYPE : CURV DEFI DEPT Dep th NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. NRAT Raw Thermal Neutron Ratio CRAT Thermal Neutron Ratio Calibrated NCNT RAW NEAR CNT COUNTS FCNT RAW FAR CNT COUNTS CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray in Casing TENS Surface Tension ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 17 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100465 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 100465 O0 000 O0 0 4 1 1 4 68 0000000000 lV~RATCNAV 100465 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 100465 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 100465 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 100465 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 100465 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 100465 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 100465 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 100465 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9417.000 NPHI.CNAV -999.250 ~T. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD -999.250 TENS.CNTD 1335.000 DEPT. 9048.000 NPHI.CNAV 12.267 ~T. CNAV 2.584 CRAT. CNAV NCNT. CNAV 8236.895 FCNT. CNAV 3186.090 CFTC. CNAV 3009.721 CNTC. CNAV GRCH. CNTD -999.250 TENS.CNTD 1460.000 -999.250 -999.250 2.704 8060.682 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE ' FLIC VERSION : O01CO1 DATE · 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE ' 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 18 FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUI~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9422.0 9046.0 CNTD LOG HEADER DATA DATE LOGGED: 23-JUL-96 SOFTWARE VERSION: CP42.2 TIME LOGGER ON BOTTOM: 1100 23-JUL-96 TD DRILLER (FT) : 9574.0 TD LOGGER (FT) : 9410.0 TOP LOG INTERVAL (FT): 9050.0 BOTTOM LOG INTERVAL (FT) : 9408.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER .................................... CNTD NEUTRON CGRS 862 CNTD NEUTRON CPSC 803 CNTD NEUTRON TDIH 817 CNTD NEUTRON CNTD 146 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 9614.0 SEA WATER THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 19 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22250 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO NEUTRON GAMMA RAY LOG DATED 17-FEB-93. THE PURPOSE OF THIS LOG WAS TO ESTABLISH CURRENT GAS OIL CONTACT. GOC IS AT 9168' THIS FILE CONTAINS RAW PASS #1 CNTD LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 11-24A Well Name APIN 500292162301 API Serial Number FL 0217' FSL & 0180' FEL Field Location SECT 28 Se c t i on TOWN 1 iN Township RANG 1SE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN J. JULIAN Wi tness Name SON 100465 Servi ce Order Number PDAT MSL Permanent da turn EPD FT O. Elevation of Permanent Datum LMF RK~ Log Measured From APD FT 54.5 Above Permanent Datum EKB FT 54.5 Elevation of Kelly Bushing EDF FT 53.5 Elevation of Derrick Floor EGL FT 28. Elevation of Ground Level TDD FT 9574. Total Depth - Driller TDL FT 9410. Total Depth - Logger BLI FT 9408. Bottom Log Interval TLI FT 9050. Top Log Interval DFT SEA WATER Drilling Fluid Type TLAB 11:00 23-JUL-96 Time Logger at Bottom LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 20 TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. RTNR Raw Thermal Neutron Ratio TNRA Thermal Neutron Ratio Calibrated RCNT RAW NEAR CNT COUNTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate GR API-Corrected Gamma Ray TENS Surface Tension CCL CCL DISCRIMINATED AMPLITUDE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100465 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 100465 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 100465 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 100465 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 100465 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 100465 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 21 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ClTTCPS1 CPS 100465 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 100465 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 100465 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PSi LB 100465 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 100465 O0 000 O0 0 5 1 1 4 68 0000000000 * * DA TA * * DEPT. 9422.000 NPHI.PS1 22.971 RTNqR.PS1 4.000 TNRA.PS1 RCNT. PS1 3392.226 RCFT. PS1 848.057 CNTC.PS1 3355.125 CFTC. PSi GR.PS1 30.031 TENS.PSi 1115.000 CCL.PS1 0.026 DEPT. 9046.000 NPHI.PS1 12.953 RTNR.PS1 2.737 TNRA.PS1 RCNT. PS1 7983.707 RCFT. PS1 3046.092 CNTC. PS1 7978.673 CFTC. PSI GR.PS1 18.453 TENS.PSi 1450.000 CCL.PS1 0.000 4.152 808.091 2. 798 2916. 593 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE · 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE · 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 22 FILE S~Y VENDOR TOOL CODE START DEPTH ........................... CNTD 9421.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD NEUTRON CNTD NEUTRON CNTD NEUTRON CNTD NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH .......... 9046.5 23-JUL-96 CP42.2 llO0 23-JUL-96 9574.0 9410.0 9050.0 9408.0 1800.0 NO TOOL NUMBER ........... CGRS 862 CPSC 803 TDIH 817 CNTD 146 9614.0 SEA WATER TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 23 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 22250 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO NEUTRON GA~ff4A RAY LOG DATED 17-FEB-9$. THE PURPOSE OF THIS LOG WAS TO ESTABLISH CURRENT GAS OIL CONTACT. GOC IS AT 9168' THIS FILE CONTAINS RAW PASS #2 CNTD $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 11-24A Well Name APIN 500292162301 API Serial Number FL 0217' FSL & 0180' FEL Field Location SECT 28 Section TOWN liN Township RANG 15E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN J. JULIAN Wi tness Name SON 100465 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 54.5 Above Permanent Datum EKB FT 54.5 Elevation of Kelly Bushing EDF FT 53.5 Elevation of Derrick Floor EGL FT 28. Elevation of Ground Level TDD FT 9574. Total Depth - Driller TDL FT 9410. Total Depth - Logger BLI FT 9408. Bottom Log Interval TLI FT 9050. Top Log Interval DFT SEA WATER Drilling Fluid Type TLAB 11:00 23-JUL-96 Time Logger at Bottom LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 24 TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. RTNR Raw Thermal Neutron Ratio TNRA Thermal Neutron Ratio Calibrated RCNT RAW NEAR CNT COUNTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate GR API-Corrected Gamma Ray TENS Surface Tension CCL CCL DISCRIMINATED AMPLITUDE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100465 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 100465 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 100465 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 100465 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 100465 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 100465 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 25 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CNTC PS2 CPS 100465 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 100465 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 100465 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 100465 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 100465 O0 000 O0 0 6 1 1 4 68 0000000000 * * DATA * * DEPT. 9421.000 NPHI.PS2 25.236 RTNR.PS2 4.286 TNRA.PS2 RCNT. PS2 3457.383 RCFT. PS2 806.723 CNTC. PS2 3419.569 CFTC.PS2 GR.PS2 29.000 TENS.PS2 955.000 CCL.PS2 0.021 DEPT. 9046.500 NPHI.PS2 13.440 RTNR.PS2 2.726 TNRA.PS2 RCNT. PS2 7796.126 RCFT. PS2 2916.497 CNTC.PS2 7684.281 CFTC. PS2 GR.PS2 18.031 TENS. PS2 1440.000 CCL.PS2 0.000 4.448 768.705 2. 865 2763. 622 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE · 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCRE~IENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 26 FILE SU~ff~%RY VENDOR TOOL CODE START DEPTH CNTD 9421.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9007.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD NEUTRON CNTD NEUTRON CNTD NEUTRON CNTD NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) '. BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER 23-JUL-96 CP42.2 1100 23-JUL-96 9574.0 9410.0 9050.0 9408.0 1800.0 NO TOOL NUMBER ........... CGRS 862 CPSC 803 TDIH 817 CNTD 146 9614.0 SEA WATER THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 27 FAR COUNT RATE LOW SCALE (CPS) '. 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22250 TOOL STANDOFF (IN): 1.0 REb~gJU~S: TIED INTO NEUTRON GAb~!A RAY LOG DATED 17-FEB-93. THE PURPOSE OF THIS LOG WAS TO ESTABLISH CURRENT GAS OIL CONTACT. GOC IS AT 9168' THIS FILE CONTAINS RAW PASS #3 CNTD $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 11-24A Well Name APIN 500292162301 API Serial Number FL 0217' FSL & 0180' FEL Field Location SECT 28 Section TOWN liN Township RANG 1SE Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN J. JULIAN Wi tness Name SON 100465 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 54.5 Above Permanent Datum EKB FT 54.5 Elevation of Kelly Bushing EDF FT 53.5 Elevation of Derrick Floor EGL FT 28. Elevation of Ground Level TDD FT 9574. Total Depth - Driller TDL FT 9410. Total Depth - Logger BLI FT 9408. Bottom Log Interval TLI FT 9050. Top Log Interval DFT SE~ WATER Drilling Fluid Type TLAB 11:00 23-JUL-96 Time Logger at Bottom LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 28 TABLE TYPE : CURV DEFI DEPT Depth NPHI Compensated Neutron Porosity, SS Matrix, cali & dead time corr. RTNR Raw Thermal Neutron Ratio TNR~ Thermal Neutron Ratio Calibrated RCNT RAW NEAR CNT COUNTS RCFT RAW FAR CNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate GR API-Corrected Gamma Ray TENS Surface Tension CCL CCL DISCRIMINATED AMPLITUDE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100465 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 100465 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 100465 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 100465 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 100465 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 100465 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 29 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CNTC PS3 CPS 100465 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 100465 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 100465 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 100465 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 100465 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9421.500 NPHI.PS3 30.508 RTNR.PS3 4.919 TNRA.PS3 RCNT. PS3 3500.000 RCFT. PS3 711.538 CNTC. PS3 3461.721 CFTC. PS3 GR.PS3 37.625 TENS.PS3 1010.000 CCL.PS3 0.021 DEPT. 9007.000 NPHI.PS3 15.535 RTNR.PS3 2.974 TNRA.PS3 RCNT. PS3 7207.207 RCFT.PS3 2509.165 CNTC. PS3 7253.763 CFTC. PS3 GR.PS3 20.469 TENS.PS3 1430.000 CCL.PS3 0.000 5.106 678.007 3.150 2301.163 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION : O01CO1 DATE · 96/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE ' 96/08/21 ORIGIN : FLIC TAPE NAME : 96212 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-24A, API #50-029-21623-01 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1996 14:22 PAGE: 30 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/08/21 ORIGIN · FLIC REEL NAME : 96212 CONTINUATION # : PREVIOUS REEL COGENT : ARCO ALASKA INC, PRUDHOE BAY, DS 11-24A, API #50-029-21623-01 O ALASKA INC D.S. 11 - 24A PRUDHOE BAY Oil & O~ts 6ons. Gore, Ar~claorage I Date, Ssi~_rt Run 1' 17 - February - 1994 DLLIZDLICNIGR 8250 t585 'G~I~88~ SNOI~D~HHOD ~NI~¥S ~0 DNIS~D ON '~AIAD~ DNI~A~I~ NSIHO 'NOI~HHOD ~OH~HO8 .~'8 'XI~k~{ ~NOASGN%fS DOE[ NO~,I, fl.~N 'SAN~HHflSk~HN 'G~[HO~ S~M NOI~¥DI~I~A NO G~N~S~H~ X~NO NO~A~N 'SS~ NIk54 S~ G~AN~S~H~ ~ ~D~N NOI~kg4HO~NI 'SS¥~ ~¥H~ ~¥ ~I~ X~ISN~G '~6-8H~-£I '00:~0 ~ GH~OAS NOI~W/~DHID 'HH~AO~ 'H 9 ~OSMHN 'H :A~ GHSSHN~IM SDO~ · ~l~ol~zl~ :smm-,~ 0'~I96 00S'8 DNI~S NOI~D~GO~ 0'~8E8 ~E9'6 9NIHAS GH£ DNIHAS GNE ONIHZS ~SI (z~) Hmaa~ (HI) azis (NI) .~ZIS &'fa SHHqqIHG DNISgfD HqOH NH~O O0'SE 08I NII £ NfiH ~ N/iH S~H HHS 00'SSI9 I NnH SHDIAHHS HNIqHHIM GH,~,krHOdHODNI k~I S k~I%f I0~E9IE6E00~ sIq :sdA$ s~ E al.~qns FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DLL SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA depth shifted and clipped curves; 0.5000 START DEPTH STOP DEPTH 8276.0 9533.0 8286.0 9585.0 8804.0 9558.0 8276.0 9538.0 GR (MEASURED DEPTH) BASELINE DEPTH LL3 8276.0 8276.0 8300.5 8300.5 8314.5 8314.5 8336.0 8417.5 8423.5 8430.5 8430.5 8432.0 8432.5 8433.0 8441.0 8443.0 8443.5 8448.5 8449.0 8449.0 8453.0 8470.5 8471.0 8478.0 8478.5 8482.5 8483.5 8483.5 8493.0 8493.5 8503.5 8504.0 8505.5 8507.5 8507.5 8511.5 8525.0 8525.0 8537.5 8548.0 8548.0 8569.0 8569.0 8578.5 8577.5 8587.5 8587.0 8602.5 8612.5 8635.0 8647.5 8657.0 8660.5 8677.0 8682.5 8683.0 8698.5 8698.5 8714.0 8714.5 8714.5 all runs merged; no EQUIVALENT UNSHIFTED DEPTH NPHI RHOB 8276.0 8276.0 8336.0 8418.0 8423.0 8432.0 8441.0 8442.5 8448.5 8453.5 8470.5 8478.0 8482.0 8504.0 8505.5 8507.5 8511.5 8537.5 8548.0 8587.0 8602.5 8612.5 8634.5 8646.5 8657.0 8660.0 8677.0 8683.5 8697.5 8715.0 8728.5 8781.0 8784.0 8786.5 8787.0 8813.0 8820.0 8820.5 8823.5 8824.0 8849.5 8857.0 8858.5 8863~0 8865.0 8870.5 8871.0 8875.5 8880.0 8886.5 8892.0 8893.5 8894.0 8900.5 8915.0 8924.0 8930.0 8932.0 8934.0 8934.5 8942.5 8945.5 8966.5 8973.0 8979.5 8980.0 8983.5 8986.5 9003.0 9003.5 9009.5 9015.5 9026.0 9030.0 9034.5 9063.5 9071.5 9087.5 9097.5 9103.0 9103.5 9104.0 9119.5 9146.0 9153.0 9166.5 9181.0 9196.0 9208.0 9214.0 8786.5 8820.0 8857.0 8864.5 8870.0 8894.0 8900.5 8915.0 8929.5 8931.5 8934.5 8946.0 8967.0 8973.0 8979.5 8983.5 8986.5 9002.5 9015.5 9063.5 9103.5 9180.0 9213.5 8728.5 8781.5 8784.0 8787.0 8813.0 8823.5 8849.5 8859.0 8863.5 8871.5 8886.5 8892.0 8979.5 9026.0 9034.0 9063.5 9071.5 9088.0 9104.0 9146.0 9181.0 8820.0 8824.5 8870.0 8874.5 8879.5 8894.0 8923.5 8934.0 8942.5 8973.0 8979.5 8986.5 9003.5 9008.5 9015.0 9030.0 9064.0 9097.5 9102.5 9119.5 9145.5 9152.0 9166.5 9181.0 9196.0 9207.5 9214.5' 9220.5 9224.5 9233.0 9237.5 9240.0 9268.0 9268.5 9292.5 9299.0 9299.5 9311.5 9312.0 9314.0 9320.5 9321.0 9330.5 9355.5 9356.0 9359.5 9362.0 9367.5 9368.0 9373.0 9374.5 9375.5 9378.5 9379.0 9381.5 9382.0 9394.0 9400.5 9404.5 9408.5 9411.5 9413.5 9431.5 9432.5 9436.0 9442.5 9445.5 9448.5 9476.0 9476.5 9477.0 9488.0 9488.5 9508.0 9512.5 9595.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DLL SDN 2435 $ 9222.5 9233.0 9239.0 9267.5 9298.5 9310.0 9320.5 9329.0 9355.5 9362.0 9368.0 9372.5 9380.5 9394.5 9408.5 9432.0 9446.0 9478.0 9488.0 9512.0 9595.0 RUN NO. 1 1 1 9240.0 9299.0 9314.0 9321.0 9331.0 9359.0 9368.5 9375.5 9379.5 9431.5 9437.0 9442.5 9449.0 9478.0 9489.0 9509.0 9595.0 PASS NO. 5 5 5 5 9213.5 9220.0 9232.0 9237.5 9240.0 9268.5 9292.5 9299.5 9311.0 9320.5 9330.0 9356.5 9359.0 9362.0 9373.0 9378.0 9382.0 9400.5 9404.5 9411.0 9413.5 9432.5 9443.0 9477.5 9491.5 9595.0 MERGE TOP 8276.0 8286.0 8804.0 8276.0 MERGE BASE 9533.0 9585.0 9558.0 9538.0 REMARKS: OPEN HOLE portion of MAIN PASS. LLD, SP, MTEM, TENS, & TEND WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. CN WN FN COUN STAT / ??MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3 .OUT $ : ARCO ALASKA INCORPORATED : D.S. 11 - 24A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 LL3 DLL 68 1 OHMM 4 3 LLD DLL 68 1 OHMM 4 4 SP DLL 68 1 MV 4 5 MTEM DLL 68 1 DEGF 4 6 TEND DLL 68 1 LB 4 7 TENS DLL 68 1 LB 4 8 RHOB SDN 68 1 G/C3 4 9 DRHO SDN 68 1 G/C3 4 10 PEF SDN 68 1 BN/E 4 11 CALl SDN 68 1 IN 4 12 NPHI 2435 68 1 PU-S 4 13 FUCT 2435 68 1 CPS 4 14 NUCT 2435 68 1 CPS 4 4 57 515 01 6 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 165 Tape File Start Depth = 9595.000000 Tape File End Depth = 8276.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: .68 39586 datums Tape Subfile: 2 416 records,,. Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH 2435 $ BASELINE CURVE FOR SHIFTS: 0.5000 START DEPTH STOP DEPTH 8250.0 8276.0 8250.0 8276.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE portion of MAIN PASS. CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 11 - 24A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 2 NPHI 2435 68 1 PU-S 3 FUCT 2435 68 1 CPS 4 NUCT 2435 68 1 CPS 5 TEND 2435 68 1 LB 6 TENS 2435 68 1 LB 4 4 08 501 10 0 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 4 4 19 912 29 5 4 4 19 912 29 5 24 * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 8276.000000 sasXq ~IOI sagXq E9 · ''spaooaa 0~ s~nswp 0£~ :q~BuaI paoDaa ~rn~x~ :q~6uaI paoDaa ~nm~u~N ~ :aI~qns 89 :apoD daH :Aawm~ns 6u~poosp spoo uo~$uasaadsa SIq ~aa& = s~u~ g~daG aI~ 00000~'0 = Bu!owds IaAa~ aI!M O00000'g~Z8 = gsdaG puM aI!g adw& Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH GR 8249.5 DLL 8249.5 ZDL 8801.0 2435 8249.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9536.0 9588.0 9578.0 9543.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL KNJT KNJT TEMP PCM MIS DLL FTS $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 17-FEB-94 FSYS REV. J001 VER. 1.1 500 17-FEB-94 1353 17-FEB-94 9614.0 9599.0 8250.0 9585.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 3967XA 1229MA/1229EA 8.500 8283.0 8276.0 XANVIS 9.80 45.0 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT ARCO ALASKA INCORPORATED D.S. 11 - 24A PRUDHOE BAY NORTH SLOPE ALASKA 5.2 162.0 0.124 0.056 0.096 0.000 0.156 0.000 THERMAL SANDSTONE 2.65 8.500 2.0 69.0 162.0 69.0 0.0 69.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E SHR ZDL 68 1 CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 37 715 66 1 4 24 115 90 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 72 * DATA, RECORD (TYPE# 0) Total Data Records: 417 994 BYTES * Tape File Start Depth = 9595.000000 Tape File End Depth = 8243.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 142358 datums Tape Subfile: 4 499 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH GR 8798.0 DLL 8798.0 2435 8798.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9554.5 9606.0 9561.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL KNJT KNJT TEMP PCM MIS DLL FTS $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 17-FEB-94 FSYS REV. J001 VER. 1.1 500 17-FEB-94 1307 17-FEB-94 9614.0 9599.0 8250.0 9585.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 3967XA 1229MA/1229EA 8.500 8283.0 8276.0 XANVIS 9.80 45.0 9.0 5.2 162.0 MUD AT ,~ MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.124 0.056 0.096 0.000 0.156 0.000 69.0 162.0 69.0 0.0 69.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 8.500 TOOL STANDOFF (IN): 2.0 REMARKS: REPEAT PASS. DENSITY DATA FROM THIS PASS MERGED & PRESENTED WITH MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 11 - 24A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 2 RS DLL 68 1 OHMM 3 RD DLL 68 1 OHMM 4 SP DLL 68 1 MV 5 TEMP DLL 68 1 DEGF 6 CHT DLL 68 1 LB 7 TTEN DLL 68 1 LB 8 SPD DLL 68 1 F/MN 9 CAL DLL 68 1 IN 10 CNC 2435 68 1 PU-S 11 CNCF 2435 68 1 PU-S 12 CN 2435 68 1 PU-L 13 LSN 2435 68 1 CPS 14 SSN 2435 68 1 CPS 4 4 57 515 01 6 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 11 639 82 1 4 4 44 339 70 5 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 205 Tape File Start Depth = 9614.000000 Tape File End Depth = 8798.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49446 datums Tape Subfile: 5 286 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS 94/ 2/28 01 **** REEL TRAILER **** 94/ 2/28 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 28 FEB 94 4:29p Elapsed execution time = 32.79 seconds. SYSTEM RETURN CODE = 0 BP Exploration Alaska Inc Well: 11-24A Field: PRUDHOE BAY UNIT North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 27th August, 2014 Report Date : 13th October, 2014 Submitted by: Farrukh Hamza Phone: +1(281)871-3048 10200 Bellaire Blvd, Houston, Texas-77072 Email: farrukh.hamza@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ............................................................................................................................. 2 2.0 BACKGROUND AND OBJECTIVES .......................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT ............................................................ 4 4.0 PRODUCTION LOG PROCESSING ........................................................................................................... 7 4.1 FLOWING SURVEY ...................................................................................................................................... 9 4.2 SHUT-IN SURVEY ...................................................................................................................................... 23 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 11-24A on August 27th, 2014 in flowing conditions with the objective of identifying the feasibility of water shut off treatment. In order to accurately quantify the flow of water, an array production logging suite was run. The flowing PL analysis showed the oil production to be coming from 3rd, 4th and 5th set of perforations. The 4th and 5th perforations (9314’ – 9320’, 9370’ – 9390’) account for 16% and 56% of the water production respectively. The 2nd and 3rd perforations (9230’ – 9235’, 9264’ – 9270’) produce 27% and 63% of the total gas production respectively. During the shut-in passes, a cross flow was observed from the bottom four perforations into the top perforation. Oil is produced from the 3rd and 5th perforations (9264’ – 9270’ and 9370’ – 9390’) and gas is produced from the bottom four perforations while water, oil and gas are injected into the first perforation (9210’ – 9219’). The reported rates are 10,561 STB/D water, 492 STB/day oil and 9600 Mscf/D gas. Interpreted rates for water, oil and gas are highe r by 13%, higher by 15% and lower by 24% respectively. Flowing: Perforations Water Rate Oil Rate Gas Rate From, ft To, ft STB/D % STB/D % Mscf/D % 9210 9219 1222 10.2 0 0.0 0 0.0 9230 9235 1167 9.8 0 0.0 1972 26.7 9264 9270 908 7.6 114 20.1 4644 63.0 9314 9320 1940 16.2 86 15.1 439 6.0 9370 9390 6702 56.1 367 64.8 319 4.3 11939 567 7374 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to allocate oil, gas and water in producing zones and identity the feasibility of water shut off treatment. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 11-24A is completed with 7” production liner across which the production log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool – Gas holdup – Caliper – Radioactive Density –Capacitance Water Holdup – Inline Spinner – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good TEMP Well bore temperature Good FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good CWH Uses capacitance to measure the differences between hydrocarbons and water Good Used qualitatively in the interpretation RAT Resistivity Array Tool Good GHT Gas HoldUp Tool Good Used qualitatively in the interpretation FLUID VELOCITY CFB Caged Fullbore Spinner Good ILS Inline Spinner Good SAT Spinner Array Tool Good 3rd spinner was excluded from the analysis (malfunctioned) . BP Exploration Alaska Production Array Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: Production Log Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable. The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model. The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers. Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps: The data preparation to filter the data, compute gradients and error estimates. The calibration of the array tools and full-bore flow meter. The computation of the layered holdup and layered flow-rates. The profile determination to identify the potential producing and/or injecting zones. The computation of the flow rates by global optimization. The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20,000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 30.2 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The Pc and Tc parameters were calculated using the Brown et al. correlation. The gas viscosity was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: GasType Miscellaneous SPGG UNITY .770 GP-CO2 UNITY 0.129 GP-H2S UNITY 0 GP-Nitrogen UNITY 0 Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: Depth Twf Pwf Bwater waterwaterBoil oiloilRsb Bgas gasgas feet °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl UNITY g/cc cP 8820 171 2655 1.02 0.996 0.393 1.24 0.769 0.991 451 0.00592 0.159 0.0193 8883 171 2670 1.02 0.996 0.393 1.24 0.768 0.987 454 0.00589 0.16 0.0194 8946.5 171 2686 1.02 0.996 0.393 1.24 0.768 0.982 457 0.00586 0.161 0.0195 9009.5 172 2701 1.02 0.996 0.393 1.24 0.767 0.978 460 0.00582 0.162 0.0195 9073 172 2717 1.02 0.996 0.392 1.24 0.767 0.973 463 0.00579 0.163 0.0196 9136 172 2733 1.02 0.996 0.392 1.24 0.766 0.969 466 0.00576 0.164 0.0197 9199.5 172 2749 1.02 0.996 0.392 1.25 0.766 0.967 469 0.00573 0.164 0.0197 9262.5 172 2765 1.02 0.996 0.393 1.25 0.766 0.964 473 0.0057 0.165 0.0198 9326 174 2787 1.02 0.995 0.387 1.25 0.765 0.959 475 0.00569 0.166 0.0199 9389 174 2801 1.02 0.995 0.385 1.25 0.764 0.947 478 0.00567 0.166 0.0199 To estimate the flow rates, the caliper log recorded during the ‘up’ and ‘down’ passes was used to estimate the nominal ID throughout the log. Tool information The following capacitance tool characteristics were used HydroWater Hz 28538 (Downhole measurement) HydroHyd Hz 34542 (Surface Calibration) The following gas holdup tool characteristics were used GasHoldupWater Hz 41720 (Downhole measurement) GasHoldupGas Hz 15592 (Surface Calibration) BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the station measurement against time. For the interpretation, all the passes have been used. Array spinner #3 malfunctioned and was excluded from the analysis. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. Both fullbore and inline spinners are showing a good response. Figure 8 shows the station measurements. From the raw data, various trends can be observed. Most of the gas production is coming from the 3rd perforation from the top (fullbore and inline spinners increase, density decreases to 0.58 g/cc & temperature decreases). Most of the water production (56%) is coming in from the 5th perforation (9370’ – 9390’) – fullbore and inline spinners increase, capacitance is at the water base-line (and fluctuates) while density (fluctuates and) decreases to about 0.83 g/cc and temperature decreases due to gas and oil being produced from the 5th perforation as well. All the oil production is taking place from the bottom three perforations – fullbore & inline spinners increase, density decreases & capacitance increases. From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 10 and 11). The calibrated RAT response is presented in Figure 12. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 13. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 14. The production rates at surface conditions estimated from the production log analysis are presented in Figure 15 and are summarized in the table below: Perforations Q-Water Qp-Water Q-Oil Qp-Oil Q-Gas Qp-Gas From, ft To, ft BFPD BFPD BFPD BFPD MCFD MCFD 9210 9219 1222 11939 0 567 0 7374 9230 9235 1167 10717 0 567 1972 7374 9264 9270 908 9550 114 567 4644 5402 9314 9320 1940 8642 86 453 439 758 9370 9390 6702 6702 367 367 319 319 BP Exploration Alaska Production Array Log Analysis 10 Raw Data - The figure below summarizes the input data recorded at the well site during flowing passes. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next 06 tracks show the RAT data for 6 active probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 13 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station BP Exploration Alaska Production Array Log Analysis 14 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore spinner (ASpinner07) and the inline spinner (Aspinner08). Array spinner #3 malfunctioned and was not used in the analysis. Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 15 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 16 Pre- Processing Figure 9: All the passes have been used in the interpretation BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 10: Velocity profile from SAT data BP Exploration Alaska Production Array Log Analysis 18 The image below displays cross plots for the Inline and fullbore spinners. The estimated slopes are used for converting the spinner response to flow velocities. Array spinner #3 malfunctioned and was turned off during the interpretation. Figure 11: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-9: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 12: Calibrated RAT response BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 13: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. Capacitance and gas holdup are used qualitatively. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 14: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 15: Flow profile at surface conditions BP Exploration Alaska Production Array Log Analysis 23 4.2 SHUT-IN SURVEY The data from the shut-in survey are presented in the Figures 16 - 28. For the interpretation, all the passes have been used. Figure 21 shows the spinner data with stationary measurements. The response of fullbore and inline spinners suggest cross-flow taking place across perforations. During the shut-in passes, a cross flow was observed from the bottom four perforations into the top perforation. This was determined qualitatively and quantitatively from spinner, density, gas hold-up and capacitance data. Oil (100 and 45 barrels) is produced from the 3rd and 5th perforations (9264’ – 9270’ and 9370’ – 9390’) and gas is produced from the bottom four perforations while water, oil and gas are injected into the first perforation (9210’ – 9219’). Across the 5th perforation (9370’ – 9390’), the (CFB and ILS) spinners and capacitance increase while density and gas-holdup decrease indicating gas production. Across the top perforation (9210’ – 9219’), CFB and ILS deflect to the left indicating fluid injection. Perforations Water Rate Oil Rate Gas Rate From, ft To, ft STB/D STB/D Mscf/D 9210 9219 -61 -151 -2693 9230 9235 0 0 370 9264 9270 0 100 182 9314 9320 13 0 221 9370 9390 50 45 1919 BP Exploration Alaska Production Array Log Analysis 24 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 16: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 25 Figure 17: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 26 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next 06 tracks show the RAT data for 6 active probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 18: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 27 Figure 19: Input data from the Resistance Array Tool (RAT) showing only the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 28 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore spinner (ASpinner07) and the inline spinner (Aspinner08). Figure 20: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 29 Figure 21: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. Last track shows SAT rotation in degrees. BP Exploration Alaska Production Array Log Analysis 30 Pre- Processing Figure 22: Passes showing a consistent response have been used in for averaging out the measurements. BP Exploration Alaska Production Array Log Analysis 31 Calibration of Spinner Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 4-9: Measured and theoretical SAT responses for each spinner. Track 10: Measured and theoretical responses for the full-bore spinner. Track 11: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 23: Velocity profile from SAT data. BP Exploration Alaska Production Array Log Analysis 32 The image below displays cross plots for the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. Figure 24: Spinner cross plot. BP Exploration Alaska Production Array Log Analysis 33 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-9: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 25: Calibrated RAT response BP Exploration Alaska Production Array Log Analysis 34 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 26: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 35 Shut-In Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exist intermittently. Figure 27: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 36 The production rates at surface conditions are presented in the figure below: Figure 28: Flow profile at surface conditions
